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Home My WebLink About206-110New Plugback Esets 6/21/2024 Well Name API Number PTD Number ESet Number Date Nikaitchuq 3 PB1 50-629-23242-70-00 205-001 T38970 9-26-2005 Nikaitchuq 3 PB2 50-629-23242-71-00 205-001 T38971 9-26-2005 Nikaitchuq 3 PB3 50-629-23242-72-00 205-001 T38972 9-26-2005 1E-24BL1 PB1 50-029-20857-70-00 212-009 T38973 4-17-2012 1E-24BL1 PB2 50-029-20857-71-00 212-009 T38974 4-17-2012 1E-24BL1 PB3 50-029-20857-72-00 212-009 T38975 4-17-2012 1J-102 PB1 50-029-23317-70-00 206-110 T38976 3-4-2008 1J-102 PB2 50-029-23317-71-00 206-110 T38977 3-4-2008 1J-102 PB3 50-029-23317-72-00 206-110 T38978 3-4-2008 1J-102L2 PB1 50-029-23317-73-00 206-112 T38979 3-24-2008 1J-102L2 PB2 50-029-23317-74-00 206-112 T38980 3-24-2008 1J-103 PB1 50-029-23318-70-00 206-114 T38981 12-12-2008 1J-103 PB2 50-029-23318-71-00 206-114 T38982 12-12-2008 1J-103 PB3 50-029-23318-72-00 206-114 T38983 12-12-2008 1J-102 PB1 50-029-23317-70-00 206-110 T38976 3-4-2008 1J-102 PB2 50-029-23317-71-00 206-110 T38977 3-4-2008 1J-102 PB3 50-029-23317-72-00 206-110 T38978 3-4-2008 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard Drive data drop 1H-111 50-029-23581-00 217133_1H-111_IPROFWFL_03JUL2023 1H-114 50-029-23584-00 217136_1H-114_IPROF_17Oct23 1H-115 50-029-23605-00 218053_1H-115_IPROF RSTWFL_09May2022 1H-116 50-029-23594-00 218012_1H-116_IPROFWFL_05Jul2023 1H-117 50-029-23602-00 218032_1H-117_PPROF-WFL_06July23 218032_1H-117_WFL_18Oct23 1H-119 50-029-23591-00 217178_1H-119_WFL_07Jul2023 1J-102 50-029-23317-00 206110_1J-102_RPPG_18Jul2023 1J-107 50-029-23366-00 207107_1J-107_PPROF_10May2022 1J-162 50-029-23360-00 207080_1J-162_LDL_03May2022 1J-170 50-029-23310-00 206062_1J-170_Temp-Pres_11Jul2023 1J-176 50-029-23364-00 207099_1J-176_LDL_11May2022 4of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38340 T38341 T38342 T38344 T38343 T38345 T38346 T38347 T38348 T38349 T38350 2/29/2024 1J-102 50-029-23317-00 206110_1J-102_RPPG_18Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-18_22568_KRU_1J-102_InjectionProfile_Transmittal.docx.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22568 KRU 1J-102 50-029-23317-00 Injection Profile 18-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 206-110 T38096 10/25/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.25 11:19:35 -08'00' 1 Regg, James B (OGC) From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Friday, October 20, 2023 9:51 AM To:NSK Optimization Engr; Regg, James B (OGC) Cc:CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael; Krysinski, Marina L; Valentine, Doug K Subject:LPP/SSV Returned to Service on CPAI Well 1J-102 on 10/19/2023 Good AŌernoon Jim, The low‐pressure pilot (LPP) on well 1J‐102 (PTD #206‐110, 206‐111, 206‐112) was returned to service aŌer the well was SI and removed from the “Facility Defeated Safety Device Log” on 10/19/2023. The well is currently shut‐in following an IPROF due to suspected interference with an offset producer. Please let me know if you have any quesƟons. Thank you, Will Parker Senior ProducƟon Engineer – GKA (CPF1‐West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK Optimization Engr <n2046@conocophillips.com> Sent: Thursday, October 12, 2023 5:57 PM To: Jim Regg <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J‐102 on 10/12/2023 Jim, The low pressure pilot (LPP) on well 1J‐102 (PTD #206‐110, 206‐111, 206‐112) was defeated today, 10/12/2023, aŌer the well was returned to injecƟon as part of the offset producer injecƟon breakthrough diagnosƟc well work. The well is currently injecƟng in the recommended rate of ~1300 BWPD at a wellhead pressure of 43 PSI. The LPP and surface safety valves (SSV) has been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be noƟﬁed when the LPP/SSV funcƟon is returned to normal, in accordance with “AdministraƟve Approval No. CO 406B.001.” Please let me know if you have any quesƟons. 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. 2 Thank you, Toon Toon Changklungdee/Emily Zanto GKA OpƟmizaƟon Engineer – ConocoPhillips Alaska Office: (907) 659‐7411 Cell: (303) 564‐7586 1 Regg, James B (OGC) From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Friday, July 28, 2023 10:34 AM To:Regg, James B (OGC) Cc:CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael; Krysinski, Marina L; NSK West Sak Prod Engr Subject:LPP/SSV Returned to Service on CPAI Well 1J-102 on 07.28.23 Good Morning Jim, The low‐pressure pilot (LPP) on well 1J‐102 (PTD #206‐110, 206‐111, 206‐112) was returned to service and removed from the “Facility Defeated Safety Device Log” on 07/28/2023 as the WHP has built above LPP setpoint since we re‐ established injecƟon a few days ago. The well is currently injecƟng at ~1550BWPD with a WHP of 185psig. The LPP had been defeated on 07/26/2022 aŌer a signiﬁcant injecƟon pressure reducƟon (due to low reservoir pressure) could not saƟsfy the LPP. This noƟﬁcaƟon is in accordance with “AdministraƟve Approval No. CO 406B.001.” Please let me know if you have any quesƟons. Thank you, Will Parker Senior ProducƟon Engineer – GKA (CPF1‐West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK West Sak Prod Engr Sent: Thursday, July 27, 2023 7:40 AM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J‐102 on 7.26.23 Good morning Jim, The low pressure pilot (LPP) on well 1J‐102 (PTD #206‐110, 206‐111, 206‐112) was defeated last night 7/26/2022, aŌer the well lost its well head injecƟon pressure due to extremely low reservoir pressure. This well recently came BOL post MBE conformance treatment, and the reservoir is very depleted, we expect WHP to build above LPP setpoints as the formaƟon is replenished and as we adjust injecƟon rates. The well is currently injecƟng at a rate of 750 BWPD and wellhead injecƟon pressure of 60 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log.” 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. 2 The AOGCC will be noƟﬁed when the LPP/SSV funcƟon is returned to normal, in accordance with "AdministraƟve Approval No. CO 406B.001." Please let me know if you have any quesƟons. Thank you, Will Parker Senior ProducƟon Engineer – GKA (CPF1‐West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com 1 Regg, James B (OGC) From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Thursday, July 27, 2023 7:40 AM To:Regg, James B (OGC) Cc:CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael; Krysinski, Marina L; NSK West Sak Prod Engr Subject:Defeated LPP/SSV on CPAI Well 1J-102 on 7.26.23 Good morning Jim, The low pressure pilot (LPP) on well 1J‐102 (PTD #206‐110, 206‐111, 206‐112) was defeated last night 7/26/2022, aŌer the well lost its well head injecƟon pressure due to extremely low reservoir pressure. This well recently came BOL post MBE conformance treatment, and the reservoir is very depleted, we expect WHP to build above LPP setpoints as the formaƟon is replenished and as we adjust injecƟon rates. The well is currently injecƟng at a rate of 750 BWPD and wellhead injecƟon pressure of 60 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log.” The AOGCC will be noƟﬁed when the LPP/SSV funcƟon is returned to normal, in accordance with "AdministraƟve Approval No. CO 406B.001." Please let me know if you have any quesƟons. Thank you, Will Parker Senior ProducƟon Engineer – GKA (CPF1‐West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com 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. KRU 1J-102PTD 2061100 1 Regg, James B (OGC) From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Tuesday, July 18, 2023 7:35 AM To:Regg, James B (OGC) Cc:CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael; Krysinski, Marina L; Valentine, Doug K Subject:LPP/SSV Returned to Service on CPAI Well 1J-102 on 7/18/23 Good Morning Jim, The low‐pressure pilot (LPP) on well 1J‐102 (PTD #206‐110, 206‐111, 206‐112)was returned to service and removed from the “Facility Defeated Safety Device Log” on 07/18/2023 as the well was shut in before we began our conformance treatment on the well. The LPP had been defeated on 07/17/2023 aŌer a signiﬁcant injecƟon pressure reducƟon (due to well communicaƟon with an offset producer) could not saƟsfy the LPP while we brought the injector online to prepare for a RPPG conformance treatment. This noƟﬁcaƟon is in accordance with “AdministraƟve Approval No. CO 406B.001.” Please let me know if you have any quesƟons. Thank you, Will Parker Senior ProducƟon Engineer – GKA (CPF1‐West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK West Sak Prod Engr Sent: Monday, July 17, 2023 3:37 PM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J‐102 on 7/17/23 Good aŌernoon Jim, The low pressure pilot (LPP) on well 1J‐102 (PTD #206‐110, 206‐111, 206‐112) was defeated on 7/17/2023, aŌer the well lost its well head injecƟon pressure due to communicaƟon with offset producer. The well is currently injecƟng at a rate of 1500 BWPD and wellhead injecƟon pressure is on track to fall below LPP trip pressure within the next hour while we are injecƟng into the well to prepare for an RPPG treatment this evening. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log.” 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. KRU 1J-102PTD 2061100 2 The AOGCC will be noƟﬁed when the LPP/SSV funcƟon is returned to normal, in accordance with "AdministraƟve Approval No. CO 406B.001." Please let me know if you have any quesƟons. Thank you, Will Parker Senior ProducƟon Engineer – GKA (CPF1‐West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com Originated: Delivered to:31-Oct-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1B-09 50-029-20655-00 N/A Kuparuk River Multi Finger Caliper Field & Processed 29-Sep-22 0 12 1J-102 50-029-23317-00 N/A Kuparuk River Injection Profile Field- Final 9-Oct-22 0 13 1J-102 50-029-23317-00 N/A Kuparuk River Injection Profile Field- Final 10-Oct-22 0 14 3G-13 50-103-20137-00 N/A Kuparuk River Multi Finger Caliper Field & Processed 21-Oct-22 0 15678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:1B-09 PTD: 181134 T372121J-102 PTD: 206110 T372133G-13 PTD: 190116 T372141J-10250-029-23317-00 N/AKuparuk RiverInjection ProfileField- Final9-Oct-22013 1J-10250-029-23317-00 N/AKuparuk RiverInjection ProfileField- Final10-Oct-2201Kayla JunkeDigitally signed by Kayla Junke Date: 2022.11.02 08:48:27 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on Well 1J-102 on 10/11/2022 Date:Tuesday, October 11, 2022 2:51:20 PM Attachments:image002.png image003.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, October 11, 2022 11:52 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: LPP/SSV Returned to Service on Well 1J-102 on 10/11/2022 Good morning Jim, The low-pressure pilot (LPP) on well 1J-102 (PTD #206-110, 206-111, 206-112) was returned to service and removed from the “Facility Defeated Safety Device Log” on 10/11/2022, as the well was shut in post-diagnostics work. The LPP had been defeated on 10/6/2022 after a significant injection pressure reduction (due to well communication with an offset producer) could not satisfy the LPP. This notification is in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, October 6, 2022 3:21 PM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-102 on 10/6/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-102 (PTD #206-110, 206-111, 206-112) was defeated on 10/6/2022, after the well lost its well head injection pressure due to communication with offset producer. The well is currently injecting at a rate of 1500 BWPD and wellhead injection pressure of 1 PSI while we are conducting communication diagnostics work. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-102 KUPARUK RIV U WSAK 1J-102 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-102 50-029-23317-00-00 206-110-0 W SPT 3525 2061100 1500 154 157 155 156 42 45 46 45 4YRTST P Adam Earl 5/7/2022 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:KUPARUK RIV U WSAK 1J-102 Inspection Date: Tubing OA Packer Depth 855 2000 1910 1900IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509102426 BBL Pumped:0.9 BBL Returned:0.6 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:00:05 -08'00' F1' -it 10c Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, February 8, 2019 2:10 PM , I To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK Optimization Engr; Autry, Sydney; Braun, Michael (Alaska) Subject: LPP/SSV Returned to Service on Well 11-102 Jim, The low pressure pilot (LPP) on well 1J-102 (PTD #206-110, 206-111, 206-112) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 2/8/2019, after wellhead injection pressure built up above the LPP setpoint. The well is currently injecting 752 BWPD at an injection pressure of 185 psi. The LPP had been defeated on 10/28/2018 after the well was returned to service after an extended shut-in period. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 • 205110 29290 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. June 4, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED 2018 RE: Injection Profile : 1J-102 AOGCC Run Date: 4/14/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: FannySari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 g� g FRS_ANC@halliburton.com 1J-102 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-33170-00 Injection Profile Log1 Color J Log 50-029-33170-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 21 6900 Arctic Blvd. $ NNW �� Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: OW WW1 Signed: • • Kr-Lt. T— -LtJ— (02_ prrt Zabiloo Re. ., James B (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, May 11, 2018 11:30 AM 5I t To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA); a lace, Chris D (DOA) Subject: Recent SW MITIAs in Kuparuk and Alpine Attachments: MIT CRU CD3-108 &CD3-112 05-10-18.xlsx; MIT KRU 1J 102 & 164 NON WITNESSED 05-09-18.xlsx; MIT KRU 1J Pad pg 1 05-09-18.xlsx; MIT KRU 1J Pad pg 2 05-09-18.xlsx Recent SW MITIAs performed in Kuparuk and Alpine. Regards, Jan Byrne/ Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 iNIWELLS TEAM conocabiffirn SCANNED JUN 012 ►8 f i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regdAalaska.Qov; AOGCC.InspectorsAalaska.aov: phoebe.brooksnalaska.aov �chris.wallaceealaska.00v OPERATOR: ConocoPhillips Alaska,Inc Kell l 51 i 7`1s FIELD/UNIT/PAD: Kuparuk/KRU/ 1J Pad DATE: 05/09/18 OPERATOR REP: Duffy/Green AOGCC REP: Well 1J-102 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2061100` Type Inj N Tubing 75 75 75 75 Type Test P Packer TVD 3524 ' BBL Pump 2.4 - IA 0 1800 ' 1710 - 1685 — Interval 4 Test psi 1500 ' BBL Return 1.4 " OA 33 38 39 39 Result P LZ- Notes: Non witnessed Well 1J-164 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2051440 Type Inj N Tubing 1340 1340 1340 1340 Type Test P Packer TVD 3424 BBL Pump 1.4 IA 140 2220 2165 2155 Interval 4 Test psi 1500 BBL Return 1.4 OA 238 241 241 241 Result , P Notes: Non witnessed Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result 11.821: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 1J 102 164 NON WITNESSED 05-09-18 ! KkuIT- & 2.- `661100 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, May 5, 2018 2:48 PM Keil 517/(46 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK Optimization Engr Subject: LPP/SSV Returned to Service on CPAI Well 1J-102 Jim, 10/ The low pressure pilot(LPP) on well 1J-102 PT 206-11 , 206-111,206-112)was returned to service and the entry removed from the "Facility Defeated Safety Device Log" today,after the well was shut in. The LPP had been defeated May1 when the well was temporarily returned to service to evaluate isolation of one of the p Y laterals. Please let me know if you have any questions. Michael Braun for Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 ��AN � 3 x From: NSK West Sak Prod Engr Sent:Tuesday, May 1, 2018 3:26 PM To: 'Regg,James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>; CPF1&2 Ops Supt<n2073@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Braun, Michael (Alaska)<Michael.Braun@conocophillips.com>; Fox, Pete B <Pete.B.Fox@conocophillips.com>; Sudan, Hari Hara <Hari.H.Sudan@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com> Subject: LPP/SSV Defeated on CPAI Well 1J-102 Jim, Today we returned well 1J-102 (PTD#206-110,206-111,206-112), a WestSak seawater injector,to service. The well ilk taking at our recommended injection rate at zero wellhead pressure, so the low pressure pilot (LPP/SSV) had to be defeated. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." 1 • • Please let me know if you have any questions. Michael Braun for Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 2 • • \CDA_ prb 2/Ato Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, May 1, 2018 3:26 PM (et 511115 /5 To: Regg, James B (DOA) ri Supv Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity S p CPF1 and 2; CPF1&2 Ors Braun, Michael (Alaska); Fox, Pete B; Sudan, Had Hara; NSK Supt;Autry, Sydney; ( ), Optimization Engr Subject: LPP/SSV Defeated on CPAI Well 1J-102 Jim, Today we returned well 1J-102 (PTD 11206-110, 206-111,206-112), a WestSak seawater injector,to service. The well i4 taking at our recommended injection rate at zero wellhead pressure, so the low pressure pilot (LPP/SSV) had to be defeated. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. •Michael Braun for Marina Krysinski / Courtney Gallo West Sak Production Engineers SOttiQ ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 1 Kg tt -(vz . • Pm 496 6/too Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, April 15, 2018 5:02 PM Z et 411616 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK West Sak Prod Engr; NSK Optimization Engr Subject: LPP/SSV Returned to Service on CPAI Well 1J-102 on 4/15/2018 Jim, The low pressure pilot(LPP) on wel 1J-1 D#206-11 206-111,206-112) was returned to service and removed from the "Facility Defeated Safety Device Log" today,4/15/2018, after the well was shut-in following the completion of wellwork. The LPP had been defeated on 4/6/2018 when the well was returned to service to perform wellwork.This notification is in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Stephanie Thomson for Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. SCANNED ,, Office: (907) 659-7234 Pager: (907) 659-7000 #497 i Prb 6, w Regg, James B (DOA) From: NSK Optimization Engr <n2046@conocophillips.com> Sent: Friday, April 6, 2018 6:16 PM 4N N/)S To: Regg, James B (DOA) c b r Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt; Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI Well 1J-102 on 4/6/2018 Jim, The low pressure pilot(LPP) on well J-102 PTD#206-110 206-111,206-112) was defeated today,4/6/2018,after the well was returned to service following wellwork.The we is currently injecting on a vacuum at rate of 1212 BWPD.The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Sydney Autry for Marina KrysinskiSCONO : West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 i I- Jac � > V O 2, ¢ en o ai E LLf-W 4 Doo v s °n o 3 `' p u EjQ C ,— r- N OC1 pm p U Q N ?c @ Y @ L y C ❑ - W CO co CO co CO CO co co co O Q m r O C C C C C C C C C t Y _c -a ,...,,- .7't N c_ C6 RI 413 14 CE1 td W 7 7 7 -7 7 '7 ? °7 ? 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'-I t ^ W Cl Z H co 0 COD r` H co_L a heti IJ 102_ • • Pm ZOO 1 too Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, January 22, 2018 10:30 PM 1r� i'oqiz To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt; Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI Well 1J-102 - 1/8/2018 Jim, The low pressure pilot (LPP) on well 1J-102(PTD#206-110, 206-111,206-112) was returned to service and removed from the "Facility Defeated Safety Device Log" tonight, 1/22/2018, when the well was shut-in after wellwork was completed. The LPP had been defeated on 1/15/2018 when the well was returned to service to perform wellwork.This notification is in accordance with "Administrative Approval No. CO 4066.001." -"- Please let me know if you have any questions. Mitch Autrey /Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED r O,z• ct 1 J- 102- • i Zao Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday,January 15, 2018 2:45 PM ` ""'( 4 61 l 6 i i To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney; Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI Well 1J-102 on 1/15/2018 Jim, The low pressure pilot(LPP) on well 1J-102 (PTD#206-110,206-111,206-112) was defeated today, 1/15/2018, after the well was returned to service to perform wellwork.The well is currently injecting on a vacuum at rate of 1525 BWPD.The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safet r�Device Log. The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Thanks, Mitch SCANNED QA.? K Mitch Autrey / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 i Regg, James B (DOA) pro Ziz 11(20 From: NSK West Sak Prod Engr <n1638@conocophillips.com> �� iI�{I Sent: Tuesday,January 9, 2018 6:27 AM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt; Autry, Sydney; Targac, Gary;,Fox, Pete B; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI Well 1J-102 - 1/8/2018 Jim, ,r The low pressure pilot (LPP) on well 1J-102 (PTD#206-110, 206-111,206-112) was returned to service and removed from the "Facility Defeated Safety Device Log" last night, 1/8/2018, when the well was shut-in after wellwork was completed. The LPP had been defeated on 1/7/2018 when the well was returned to service to perform wellwork. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski /Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 sCANNED 1 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, January 8, 2018 8:51 PM f l l ) 1 I i e To: Regg, James B (DOA) r Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI Well 1J-102 on 1/7/2018 Jim, The low pressure pilot (LPP) on well 1J-102 (PTD#206-110,206-111, 206-112) was defeated yesterday, 1/7/2018, after the well was returned to service to perform wellwork.The well is currently injecting on a vacuum at rate of 1531 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski /Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 i 0 If) 0 • a O L 0toc'� � � � > @ 0❑ LO .yr,.. Y O 0U' N z C O u v, 4-+ >?m a` a c c + v o Q (a }vj (_O '� -a W Q CO 'O a. = C < 0 CO co 0o co ooco 0 6 CO a�g C C C C C C ' 4 -0 O N fttt^^^ C `2 0 CO f6 f0 CO to C (p C fy 7 M C U '� N to H a to N) c0 co 0 O @ }' t- C vt QZ ;` — u 'a ro 0 }+ a > E -a v Z O O c L r0 0 (o a) 'O it' vu O ❑ ❑ ❑ ❑ J J J J J J c oD �a LO y W CU H N. LL LL LL LL LL ++ Q, N 4) "a a _o > L I- a a a a a a Z azzzzzz a t ai 0 a`, bC LL LL LL LL LL LL C C > — u N G., c t,: co v co C v * ,_c0 Q E E a u 0 z v+ 0- v U > U 0 c O - w (o L H> u c C7 `i ~ C co a O O 2 .( Q QI a N C a V 61 a. 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N �a �, ca a a Q S N z a\-1)f4 4 E Z CO w C '-' to ,n To = ,5 53 m -C v (13 OCO2 d a Q F`- O d Q ( Jif 26'6 (I CJ Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> (l zI'y� ( Sent: Saturday, March 04, 2017 6:10 PM "l To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt; Effiong, Michael; Stanley, Scott M Subject: LPP/SSV Returned to Service on CPAI well 1J-102 - 03.04.2017 Jim, The low pressure pilot(LPP) on well 1J-102 (PTD#206-110, 206-111, 206-112)was returned to service and removed from the"Facility Defeated Safety Device Log" on 03/04/2017. The well is currently injecting at approximately 1970 BWPD with a wellhead injection pressure of 110 psi. The LPP had been defeated on 01/04/2017. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 scpipQED taf, 1 a017. Pager: 1 907 659-7000 pg. #497 Email: n1638(a�conocophillips.com 1 2-- PM ?&( ( o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday,January 04, 2017 7:23 PMell ''' To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt Subject: Defeated LPP/SSV on CPAI well 1J-102 Jim, The low pressure pilot(LPP) on well 1J-102 (PTD#206-110, 006-111, 206-112)was defeated today, 01/04/2017, after the well head injection pressure fell below 100 psig. - - - - d surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 1345 BWPD at a wellhead injection pressure of-5 psig. The AOGCC will be notified when the injection pressure has increased to above 100 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Thank you. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 Email: n1638(a�conocophillips.com SCANNED MAY 2017 • i4€0, 15-I0-a_ • Regg, James B (DOA) 2.66 From: Regg, James B (DOA) I Z ( 16Sent: Tuesday, December 13, 2016 10:01 AM . ` 1 To: 'NSK West Sak Prod Engr'; CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr; NSK Optimization Engr; CPF1 DS Operators; Sullivan, Michael;Targac, Gary Subject: RE: LPP/SSV Returned to Service on Well 1J-102 PTD#s are wrong—should be 2061100, 2061110, 2061120 There are 2 ways that wells are typically reported when using the PTD number; I'll use 1J-102 for illustration: - PTD 206-110 - PTD 2061100 (this version is used when we are importing info from an report directly into our data management system; for example, a SVS or BOPE test) These reference the same well; if you use the 2nd version, do not replace the dash with a zero; instead, drop the dash and append a zero. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 C(005) j4.1 i7157 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent:Tuesday, December 13, 2016 9:26 AM To: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com>; CPF1&2 Ops Supt<n2073@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF1 DS Operators<n1275@conocophillips.com>; Sullivan, Michael <Michael.Sullivan@conocophillips.com>; Targac, Gary<Gary.Targac@conocophillips.com>; Regg,James B (DOA) <jim.regg@alaska.gov> Subject: LPP/SSV Returned to Service on Well 1J-102 Jim, The low pressure pilot(LPP) on well 1J-102 (PTD#2060110, 2060111, and 2060112)was returned to service and removed from the safety defeat log o 12/13/2016, as we11I9 ad pressures have stabilized above the LPP set point of 100 psig. This well is currently injecting 1085 BWPD ata wellhead injection pressure of 116 psig. The LPP had originally been defeated since 10/22/2016. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. 1 Thanks! Marina Krysinski for: Scott Stanley/Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000#497 n1638Cu)conocophillips.corn 2 STATE OF ALASKA • ANOKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown Performed: Suspend r Perforate r Other Stimulate r Alter Casing E Change Approved Program r Plug for Redrill E Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystel Seal MBE Trtmnt P- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory E 206-110 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23317-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,ADL 25662 KRU 1J-102 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11025 feet Plugs(measured) 5050 true vertical 3769 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 0 true vertical 0 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120 120 SURFACE 2600 10 3/4 2643 2255 INTERMEDIATE 5880 7 5/8 5920 3741 A LINER SLOTTED 4891 4 1/2 10040 3746 RECEIVED Perforation depth: Measured depth: 5923-9987 NO V 0 3 2016 True Vertical Depth: 3741 -3746 SCANNED 1 22017 AOGCC Tubing(size,grade,MD,and TVD) 4.5, L80,4707 MD, 3533 TVD Packers&SSSV(type,MD,and ND) PACKER-HRD Liner Top Packer @ 5150 MD and 3625 ND NIPPLE-CAMCO DB Nipple 3.875"NO GO PROFILE @ 516 MD and 514 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - Shut-In - Subsequent to operation - - Shut-In - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development fl Service F Stratigraphic I' Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas E WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ F WAG r GINJ E SUSP r SPLUG E 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: 315-659 Contact John Peirce(a.265-6471 Email John.W.Peircea.conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature / f f� Phone:265-6471 Date/fr11/3/16/r�/j / P-7-1, 3/2 / )-7 Form 10-414 Revised 5/2 15 '77RBDMS to--NOV - 7 2016 Submit Original Only t' • • 1J-102 DTTMSTARJOBTYP SUMMARYOPS 11/14/15 MISC. Performed fullbore Crystal Seal MBE treatment @ 1-3 bpm into MBE. CAPACITY Placed 2310#of 1-2-4 mesh Crystal Seal slurry ramping up to max. SUSTAINMENT concentration of 0.28 ppg, Slurry was underdisplaced w/30 bbls SW&46 bbls diesel. Note: will attach treatment report once available. 11/16/15 PUMPING TRACI PUMPED 40 BBLS OF DIESEL DOWN THE TUBING @ .6 BPM FOR INJECTIVITY TEST. JOB COMPLETE. 1/7/16 PUMPING TRACI FREEZE PROTECT, PUMP 7 BBLS METHANOL UP FLOWLINE, PUMP 36 BBLS DIESEL DOWN TUBING. JOB COMPLETE. 4/26/16 MISC. Performed fullbore Crystal Seal MBE treatment @—1-3 bpm into MBE. CAPACITY Placed 2970#of 1-2-4 mesh Crystal Seal slurry @ average 0.27 ppg SUSTAINMENT concentration, Slurry was left underdisplaced w/41 bbls SW&35 bbls diesel. Note: will attach treatment report once available. 5/15/16 MISC. Clean out ice and slush from 400'down to 1,856'. Continue RIH CAPACITY performing a Fluff n' Stuff untilizing SSW w/Safelube down coil and SUSTAINMENT backside. Clean down to near lockup at 10,124' CTMD. No indications of CrystalSeal bridges or fill seen. Well freeze protected. ***Job complete*** 10/11/16 PUMPING FREEZE PROTECT, PUMP 5 BBLS METHANOL UP FLOWLINE, PUMP TRACKING 38 BBLS DIESEL DOWN TUBING. JOB COMPLETE. ONLY 10/13/16 MISC. MARCIT GET TREATMENT OF MBE: PUMPED SEAWATER FLUSH CAPACITY FOLLOWED BY LINEAR POLYMER TAKING RETURNS TO FLOWBACK SUSTAINMENT UNIT AT 1J-159 TO DETERMINE MBE VOLUME. IDENTIFY RETURNS OF POLYMER AT 1J-159 AND USE 60 BBL MARCIT TREATMENT VOLUME (80 BBL ESTIMATED MBE VOLUME LESS 20 BBL SAFETY FACTOR). PUMP 60 BBL MARCIT GEL (10,000 PPM, 30:1 CROSSLINK, 5%ACCELERANT)AND DISPLACE TO MBE WITH LINEAR POLYMER, SEAWATER, AND 42 BBL OF DIESEL FREEZE PROTECT. JOB COMPLETE. • KUP 1J-102 ConocoPhiliips Well Attribu Max Angl D TD Alaska Inc, Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) • ConoCohligips 500292331700 WEST SAK INJ 94.25 6,155.17 11,025.0 ... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-102,11/29201610.23:33 AM SSSV:NIPPLE 100 8/14/2012 Last WO: 44.29 10/4/2006 Vortical scMmahc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:Crystal Seal Job,SEE NOTES pproven ifii 'i 1l41 1 . HANGER;35.8 L.,Casing Set Depth Set Depth wd lig Description• 1 _• 1 11 •11 (TVD)... 11 11 Welded•iiim Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I... .1 Top Thread CONDUCTOR;40.0-120.0 19.950 1 45.50 L-80 BTC NIPPLE;515.9 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth OMB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' ;( ' Casing Description OD(in) ID(int Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE;42.5-2642.8 •1 :1 hog Liner Details GAS LIFT;2,789.2 AUK Nominal , ff. Top iftKEI) Top(TVD)(ftKB) Top Inc!(9) Item Des Com (in) I I ',1 GAS LIFT;4,486.4 • Lusist ISO SLEEVE;4,631.0 IIIIiI? 'i: • 1 SLEEVE-C;4,631.4 g�-1 . 1ME7 4,716.6 3,535.3 75.54 HANGER LEM Above Hook Hanger 3.668 LOCATOR;4,67.1 4,862.9 3,567.1 77.80 SEAL Seal Assembly 4.000 SEAL ASSY;4,660.8 1r Casing Description IOD(in) IID(in) 'Top(ORB) Set Depth(ftKB) ISet Depth(TVD)...I Wt/Len(1...'Grade Top Thread L_. D LINER HH 4 1/2 3.688 4,727.214,984.91 3,591.9 11.601L-80 Buttress Liner Details I Nominal ID ISO SLEEVE;4,7300 ' ari. Top(ftKB) Top(ND)(ftKB) Top Incl(9) Bent Des Com (in) 4,727.2 3,537.9 76.12 HANGER FLANGED HOOK HANGER 3.990 4,744.0 3,541.8 77.03 HANGER FLANGED HOOK HANGER 3.990 4,802.5 3,554.2 77.79 ECP PAYZONE EXTERNAL CASING PACKER 3.950 ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...VJNLen(1...Grade Top Thread B LINER LEM I 4 1/21 3.5631 4,836.91 5,191.61 3,632.61 12.751L-80 1 Liner Details _a Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Indy) Item Des Com (in) D LINER LEM;4,672.7-0,866.2 ,. ,. 4,836.9 3,561.5 77.72 PACKER ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 109-47 Casing Seal Bore receptacle 4.750 4,875.7 3,569.8 77.91 XO Bushing XO Bushing 4.500 D LINER HH;4,727.2-4,984.9 5,036.4 3,602.1 78.69 HANGER LEM Above Hook Hanger 3.958 5,047.1 3,604.2 78.66 HANGER LEM Below Hook Hanger 1958 TYPE I DIVERTER;5,0470 5,081.4 3,611.0 78.47 NIPPLE CAMCO"DB"Nipple 3.563 PLUG;5,049.0 'I/ Coding ' 5,188.4 3,632.0 79.80 SEAL ASSY BAKER Seal Assembly 3.890 1. Description (00 bin) (10(i) !Top(ftKB) 'Set Depth(ftKB) (Set Depth(TVD)...'Wt/Len()...'Grade (TopThread B LINER HH 41/2 3.688 50461 5,296.0 3,648.4 1160 L-80• Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,046.1 3,604.0 78.67 HANGER Baker Model B1 Hook Hanger-above 4.500 5,062.9 3,607.3 78.58 HANGER Baker Model B1 Hook hanger-below 4.500 tl 4 5,118.4 3,618.4 78.27 ECP Baker Payzone External Csg PKR 4.500 '^' Casing Description IOD(in) 11D(in) I Top(ftKB) Set Depth(ftKB) (Set Depth(ND)...WULen(I...'Grade rTop Thread B LINER LEM;4,836.9-5,191.6iw A LINER Slotted 41/2 3.476 5,149.7110,040.4 3,746.2111.60L-80 I Buttress Liner Details Nominal ID 0 LINER HH;5,046.1-5,296.0 Top(ftKB) Top(ND)(MB) Top Incl C) Item Des Com (in) I : I 5,149.7 3,624.8 78.64 PACKER "HRD"Liner top packer 5.500 INTERMEDIATE;40.4-5,9200 5,168.6 3,628.4 79.20 NIPPLE "RS"Packoff Seal Nipple 4.870 5,171.0 3,628.8 79.28 HANGER FlexLock Liner Hanger 5.510 - _ 5,180.4 3,630.6 79.56 SBE 190-47 Casing Seal bore extension 4.750 5,200.1 3,634.0 80.15 XO BUSHING Cross Over Bushing 3.930 9,993.7 3,745.8 89.36 ECP Swell Packer Rubber Element 3.476 Tubing Strings Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection - TUBING 1String 41/21 3.9581 35.81 4,707.51 3,533. 0) 12.601 L80 IIBT-mod Completion Details Nominal ID - •- Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 35.8 HANGER VETCO GRAY TUBING HANGER, Drifted 3.885" 3.900 _ _ 515.9 513.6 12.36 NIPPLE CAMCO DB Nipple 3.875"NO GO PROFILE 3.875 4,631.5 3,510.8 71.27 SLEEVE-C BAKER MODEL CMU.Profile 3.812"CAMCO"DB". 3.812 - - - (CLOSED 10/20/2006) - - 4,679.1 3,525.3 73.50 LOCATOR LOCATOR 3.990 4,680.8 3,525.8 73.60 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY.Size 192-47. 3.880 SLOTS;5,923.0-9,9870-_ _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl - •- Top(ftKB) (ftKB) (•) Des Com Run Date ID(in) _ _ 4,631.0 3,510.7 71.25 ISO SLEEVE SET ISO SLEEVE ACROSS SLEEVE AT 4631' 9/2/2015 2.250 4,730.0 3,538.6 76.27 ISO SLEEVE TYPE II ISO SLEEVE IN D SAND LAT 6/9/2015 2.500 5,047.0 3,604.1 78.66 TYPE I TYPE I DIVERTER IN B SAND LAT 6/9/2015 3.000 - - DIVERTER - - 5,049.8 3,604.7 78.65 PLUG 3.652"DB PLUG W/PRONG AND FISH NECK 6/8/2015 0.000 PROFILE A LINER Slotted;5,149.7- 10,040.41 KUPill 0 1J-102 ConocoPhillips Oz Alaska.Inc - ConocoPhdhps ' 1J-102,11/2/2016 1023.34 AM Vertical50 m8F(9sap... HANGER;358 Ill?il !_ �. Perforations&Slots ■■ R; ■EShot [-'.,00- Shot I I ^11 Top(TVD) Btm(TVD) (shots/ Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com s.ti CONDUCTOR;40.0-120.0- 5,923.0 9,987.0 3,741.5 3,745.7 WS A2,WS 9/10/2006 32.0 SLOTS All Perfs in this well: NIPPLE;515.9 A3,1J-102 Alternating solid/slotted pipe-0.125"x2.5"@ 4 SURFACE,42.52,842.8 circumferencial adjacent rows,3"centers GAS LIFT:2,7e9.2II staggered 18 degrees,3' non-slotted ends la GAS LIFT;4,486.4 ISp' Mandrel Inserts AM at ISO SLEEVE;4,631.0 ti - on Top(TVDI Valve Latch Port Size TRO Run SLEEVE-C;4,831A 11!.'.1' N - Top(ftKB) (ftKB) Make Model OD tin) Sery Type Type (In) (psi) Run Date Corn 1 2,789.2 2,362.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000' 0.0 10/3/2006 LOCATOR;4,879.1 2 4,486.5 3,458.1 CAMCO KBMG 1 GAS LIFT -DMY 'BK-5 ' 0.000 0.0 9/9/2015 SEAL ASSY,4,880.8 - Notes:General&Safety End Date Annotation ;Il i 12/27/2007 NOTE:MULTI-LATERAL WELL: 1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) `t ?' 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 ISO SLEEVE;4,730.0 R- 7/3/2014 NOTE: EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' 9/18/2015 NOTE:FullBore MBE treatment per design placing`290 bbls 3%KCL/4 mil Crystal Seal slurry 9/1.8/2015 NOTE: into formation(37958 of CS) 11/14/2015 NOTE:concentration of 0.28 ppg 11/14/2015 NOTE:FullBore MBE treatment per design Placed 23108 of 1-2-4 mesh Crystal Seal slurry xix 4/26/2016 NOTE:FullBore Crystal Seal B MBE treatment.Placed 29708 of 1-2-4 mesh 3as 4/26/2016 I NOTE:Crystal Seal slurry @ average 0.27 ppg concentration D LINER LEM;4,672.7-4,866.2 MI D LINER HA;4,727.2-4,984.9 , IL..III TYPE I DMERTER;5,047.0 :Il-11 PLUG;5,0498I-�Ii1 Iti 4 ![i l .. B LINER LEM,4,836.9-5,191.8 B LINER HH;5,048.1-5,296.0 I I INTERMEDIATE,40.4-5,920.0 - I I - - - ! 1 - - I ! _ SLOTS;5,923.0-9,987.0 i _ - s A LINER Slotted,5,149.7- 10,040.4N ( • • Pik I J-1 u z-- Pit ZJ(/(oo Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, September 05, 2016 4:26 PM q7/1 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Haakinson, David; Braden,John C Subject: LPP/SSV returned to service on CPAI well 1J-102 The low pressure pilot (LPP) on well 1J-102 (PTD#206-110, 206-111, 206-112) was returned to service yesterday, 9/04/16, with a pilot setting of 100 psig.The well has stabilized at a wellhead injection pressure of 160 psig and rate at 845 BWPD, and has been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Please let me know if you have any questions. Regards, sCANNED JUN 2 7 20i/ Scott Stanley / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • KR. \s- t z Pit 2-6(9 t t o o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, August 18, 2016 4:16 PM y?,,,2 Sl (h To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr Specialist; CPF1 Prod Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on CPAI well 1J-102 Jim, The low pressure pilot (LPP) on well J-102 (PTD#206-12O6-111, 206-112) was returned to service today, 8/18/16, with a pilot setting of 100 psig.The well has stabilized at a wellhead injection pressure of 170 psig and rate at 1000 BWPD, and has been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCANNED JAN 2 7 2017 • • 1 U- /0.2_. Regg, James B (DOA) "_ no From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday,July 17, 2016 7:57 AM - 7'e,`t 71/6,►� To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI 1J wells Jim, The low pressure pilots (LPP) on the following wells were defeated today, 7/17/16, after water injection service was restored to drillsite 1J following the CPF-1 facility shut down. 1J-102 (PTD#206-110!206-111, 206-11 L 1J-118 (PTD#206-176, 206-177,206-178) 1J-122 (PTD#207-070, 207-071, 207-072) 1J-127 (PTD#206-047,206-048, 206-049) EV JAN 1J-136 (PTD#206-154, 206-155) 1 1J-154(PTD#205-035, 205-036,205-037) 1J-156(PTD#206-067, 206-068,206-069) The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." All injectors are on water injection and stable with building wellhead injection pressures. The AOGCC will be notified when each well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." (.- Please Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com • • J-10 P Z0( l (oo Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, May 16, 2016 5:57 PM l s(z � t� To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; Haakinson, David Subject: Defeated LPP/SSV on well 1J-102 Jim, The low pressure pilot(LPP)on well 1J-102 (PTD#206-110, 206-111, 206-112)was defeated today, 5/16/16, after the well was brought online after a shut-in period. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Tyler Hall / David Haakinson West Sak Production Engineers SCANNED SEP 2 3 2016 ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • • PTO Zo6 - // v Loepp, Victoria T (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Thursday,January 07, 2016 2:35 PM To: Loepp, Victoria T (DOA) Subject: RE: Sundry Requirement to Retreat 1J-102 with Crystal Seal for a Third Time(PTD 206-110, 315-659) Follow Up Flag: Follow up Flag Status: Flagged NNED MAY 1 9 2Q16 Victoria, Thanks. I will proceed with 3rd Crystal Seal MBE treatment on 1J-102 under the approved sundry and then file a 10-404 for all Crystal treatments. John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@talaska.gov] Sent: Thursday, January 07, 2016 2:01 PM To: Peirce, John W Subject: [EXTERNAL]RE: Sundry Requirement to Retreat 1J-102 with Crystal Seal for a Third Time John, Go ahead and pump the 3rd MBE treatment under the approved sundry and file a 10-404 that includes all treatments. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov 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 Victoria Loepp at(907)793-1247 or Victorialoem@alaska.gov From: Peirce, John W [mailto:John.W.PeirceOconocophillips.com] Sent: Thursday, January 07, 2016 1:56 PM To: Loepp, Victoria T(DOA) Cc: Haggerty-Sherrod, Ann (Northland Staffing Services) Subject: Re: Sundry Requirement to Retreat 1J-102 with Crystal Seal for a Third Time 1 • • Hi Victoria, We pumped a Crystal Seal Retreatment on 1J-102L1 (on 11/14/15)and pumped another 2,310 lbs of Crystal Seal to the MBE as per Sundry approval (attached below). We were not able to get the well back on injection until 10 days ago to test the job. Since 1J-102L1 was brought back on injection 10 days ago it has been looking like a good Crystal Seal treatment, but last night the treatment suddenly broke down. The breakdown indicator was offset 1J-159 producer very suddenly going from 15%to 99%WC at the same time that 1J-102 suddenly fell from 350 psi WHIP to 0 psi WHIP at 650 BWPD. Both wells were SI due to the failed Crystal Seal job.This leaves the B MBE open again between 1J-102 and 1J-159. I don't see that we filed a 10-404 Report yet for the treatment that just failed. Question: We would like to pump a 3rd Crystal Seal MBE treatment now. Shall we send in a 10-404 to close out the current Sundry Approval(attached below)for the job that just failed,or is it OK to continue with plans to pump another retreatment under the same 10-403 approval number? I would pump the retreatment the same way we pumped the treatment that just failed. If I can use the current approval number it reduces some paperwork and accelerates action on the well getting a retreatment pumped. I plan to pump the retreatment the same way that we pumped the treatment that just failed. However, if AOGCC prefers we first close out the current 10-403 by sending in a 10-404 for the failed treatment,then draft up a new 10-403 to seek approval for the next retreatment,then we'll proceed that way. Please advise what Sundry requirements are acceptable to AOGCC,and I will proceed accordingly. I think we have some challenging very MBE's to treat and 1J-102 is one of them. Perhaps with persistence and some better luck we'll get the MBE shutoff on the next treatment. I will be pumping the 1D-139 Crystal Seal retreatment this weekend. The 1C-190 Crystal Seal job pumped 9/21/15 is holding nicely at full target WHIP and 350+ BOPD at offset 1C- 184, so we have had some success on that MBE treatment. The 1E PWI supply line repairs are due to be completed March 2016,so we will test the 1E-105L1, 1E-102,and 1E-119 Crystal Seal MBE treatments after we can get PWI back on to those wells. Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office 2 • WELL LOG TRANSMITTAL#902815272 DATA LOGGED /l0/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 6, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper (MFC): 1J-102 Run Date: 10/8/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1J-102 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23317-00 SCANNED tsk PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Si ned:M g 6e-teat OFT 411 • � %%� THE STATE Alaska Oil and Gas �►.�-- �,�, ofALAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®F *' Q, Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce � 152.� Sr. Wells Engineer � � I ConocoPhillips Alaska, Inc. P.O. Box 100360 (1.02 - 1 /t) „1/ Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-102 Sundry Number: 315-659 Dear Mr. Peirce: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a/67 73);4-41,1--t--‘__ Cathy P. Foerster Chair DATED this Zg day of October, 2015 Encl. RBDMS N 0 2 2015 STATE OF ALASKA Allk KA OIL AND GAS CONSERVATION COMI ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE Treatment P 1 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 206-110 • 3.Address: Stratigraphic r Service 17 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-23317-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? / Will planned perforations require spacing exception? Yes r No 17 KRU 1J-102 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,25662- Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth Mo(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11025 • 3769 • 10040' ' 3746' 4 5050' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120' 120' SURFACE 2600 10.75 2643' 2252' V INTERMEDIATE 5880 7.625 5920' 3741' �T E. A LINER SLOTTED 4891 4.5 10040' 3746' O C i 2 1. 2015 ors to (� AOGPerforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slotted liner from 5923-9988 3742-3746 4.5 L80 4708 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=4673 TVD=3524 PACKER-ZXP LINER TOP PACKER MD=4837 TVD=3562 • PACKER-"HRD"LINER TOP PACKER MD=5150 TVD=3625 d NIPPLE-CAMCO DB Nipple 3.875"NO GO PROFILE MD=516 TVD=514 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Stratigraphic r Development Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/15/2015 OIL r VVINJ 17 • WDSPL r Suspended fl 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophillips.com Printed Name John Peirce Title: Sr.Wells Engineer Signature tt—'C--- Phone:265-6471 Date 1012 c 7 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3i5- (05'7 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [+1] Subsequent Form Required: _ /., le Approved by: a/PCOMMISSIONER APPROVED BY THE COMMISSION ON Date:/e) '22—/5— vi---i, 22—/5— V /, /45— AppVv a p a l i r 12 months from t e to of approval. Form 10-403 Revised 5/2015 /Ail /9(43/4s- RBD1V46.0, Submi FQr '` i c Mt • • • 1J-102L1 to 1J-159L1 B Sand MBE Treatment Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with laterals in West Sak A, B, & D sands. On 3/2/08, a 1J-102 MBE occurred to offset producer 1J-159. A 4/23/08 1J-102 main-bore IPROF saw all PWI entering 1J-102L1. A 2008 1J-102L1 IPROF RIH stuck the BHA in the B Diverter. After lengthy fishing to retrieve all of the fish, a B Iso-Sly was set 9/28/08 before diagnosing the B MBE location. 1J-102 was on PWI to A & D sands only until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate the A lat, then a B Diverter and a D Iso-Sly were set 6/9/15. A 6/10/15 IPROF in 1J-102L1 to 11109' MD found a heel MBE at -5350' RKB at the first slotted joint below the B LEM. On 9/18/15, a fullbore Crystal Seal job was pumped -3 bpm (per 10-403 Sundry Approval #315-449) to fill the B MBE. A total of 3,795 lbs of 4 mm Crystal Seal was displaced to the MBE resulting in final net treating pressure gain of 640 psi. This job took the largest Crystal Seal volume ever pumped to treat any West Sak MBE. On 9/23/15, 1J-102L1 was returned to PWI, but on 10/4/15 offset producer 1J-159 pressure & temperature rapidly increased indicating that the MBE treatment frornlJ-102L1 to 1J-159 had failed. The MBE volume is probably quite large and will need more Crystal Seal to seal it. A fullbore Crystal Seal Retreatment is proposed to seal the B MBE to return 1E-102L1 to PWI. Procedure: Pumping: 1) Fullbore pump a -10 bbl Inj test with Seawater to -3 bpm to verify good injectivity. Continue pumping Crystal Seal Slurry down tubing made with 4 mm mesh Crystal Seal at 0.25 ppg in Seawater to seal the B MBE. Hold constant -3 bpm Crystal Seal treatment rate to monitor MBE treatment response and possible Crystal Seal screenout during slurry pumping. If screenout develops, attempt to pump 80 bbls of Diesel Flush down tubing to displace Crystal Seal to B MBE. Tubular volume is 81 bbls from surface to MBE. If screenout is not seen, but 1000 psi max WHP target has been reached, swap to 35 bbls Diesel to FP to 2000' TVD followed by SD. RD. Coil Tubing: 2) RIH with 2" OD Jet Swirl Nozzle BHA to get through 2.25" ID CMU Iso-Sly (already set) to jet through Crystal Seal to as deep as possible to shear/ mechanically break all Crystal Seal remaining in the liner. POOH w/CT. RD. Put 1 J-102L1 on PWI to evaluate results of the B MBE treatment for a period long enough to verify a successful B MBE treatment exists before executing remaining work. 3) RIH with IPROF BHA on CT to pass through 2.25" ID CMU Iso-Sly. Memory log down and up passes to verify the B MBE is sealed or still taking PWI. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-102L1 to PWI service. If no indication of a B MBE, normal up PWI to all 3 laterals as follows: 4) RIH & pull the 2.25" ID Iso-Sly (from leaky CMU Sleeve) at 4631' RKB. 5) RIH & pull the `D' Iso-Sly set across the D LEM at 4730' RKB to open the D lat to PWI. 6) RIH & pull the `B' Diverter set in the B LEM at 5047' RKB. 7) RIH & pull Prong and 3.562" Plug set at 5081' to open the A lat to PWI. 8) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv. Perform MIT-IA to verify good set integrity of Iso-Sly prior before returning 1J-102 to PWI service to all 3 laterals. r KUP INJ • 1J-102 - ConocoPhillips Well Attributes Max Angle 8 MD TD Alaska 11X Wellbore API/UWI Field Name Wellbore Status ncl 0) MD(ftKB) Act Btm(ftKB) crresset;lriigpe 500292331700 WEST SAK INJ 9425 6,155.17 11,025.0 °°° Comment I12S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-102,9/13/201532232 PM SSSV:NIPPLE 100 8/14/2012 Last WO: 44.29 10/4/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O lehallf 9/13/2015 HANGER',358 I 11110-1 Casing Strings ,.. _ y,.. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread 1111)11CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread .AhJ CONDUCTOR;40.0.120.0 • SURFACE 103/4 9.950 42.5 2,642.8 2,255.0 45.50 L-80 BTC NIPPLE;5159 Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 40.4 5,920.0 3,741.1 29.70 L-80 BTC-mod SURFACE;42.5-2,642.8-ICasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D LINER LEM 4 1/2 3.688 2.7 4,866.2 3,567.8 12.60 L-80 IBT-mod GAS LIFT;2,7892 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 0) Item Des Com (in) GAS LIFT;4,486.4 4,672.7 3,523.5 73.15 PACKER ZXP Liner Top Packer 4.940 4,691.7 3,528.8 74.19 SBR '109-47 Casing Seal Bore receptacle 4.750 ISO SLEEVE; SLEEVE G;4,631.4.‘4,fi31.04,711.3 3,534.0 75.26 XO Bushing XO Bushing 3.930 4,716.6 3,535.3 75.54 HANGER LEM Above Hook Hanger 3.668 4,727.2 3,537.9 76.12 HANGER LEM Below Hook Hanger 3.688 LOCATOR;4,679.1 SEAL ASSY;4,680.8 - u 4,862.9 3,567.1 77.80 SEAL ,Seal Assembly 4.000 Casing Description IOD(in) IID(in) Top(ftKB) I Set Depth(ftKB) I Set Depth(ND)...I Wt/Len(I...I Grade 1 Top Thread D LINER HH 4 1/2 3.688 4,7272 4,984.9 3,591.9 11.60 L-80 Buttress }. Liner Details r Nominal ID ISO SLEEVE;4,730.0 1 1 Top(ftKB) Top(ND)(ftKB) Top Incl 0) Item Des Com (in) 11 4,727.2 3,537.9 76.12 HANGER FLANGED HOOK HANGER 3.990 4,744.0 3,541.8 77.03 HANGER FLANGED HOOK HANGER 3.990 4,802.5 3,554.2 77.79 ECP PAYZONE EXTERNAL CASING PACKER 3.950 Casing Description IOD(in) IID(in) Top(ftKB) Set Depth(ftKB) I Set Depth(ND)...I Wt/Len(I...I Grade I Top Thread B LINER LEM 4 12 3.563 4,836.9 5,191.6 3,632.6 1235 L-80 Liner Details Nominal ID D LINER LEM;4,672.74,866.2 Top(ftKB) Top(ND)(ftKB) Top InclI") Item Des Com (in) 7:... 4,836.9 3,561.5 77.72 PACKER ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 109-47 Casing Seal Bore receptacle 4.750 D LINER HH;4,727.24.984.9 4,875.7 3,569.8 77.91 XO Bushing XO Bushing 4.500 ,, 5,036.4 3,602.1 78.69 HANGER LEM Above Hook Hanger 3.958 5,047.1 3,604.2 78.66 HANGER LEM Below Hook Hanger 3.958 TYPE I DIVERTER;5,047.0 5,081.4 3,611.0 78.47 NIPPLE 'CAMCO"DB"Nipple 3.563 PLUG;5,049.85,188.4 3,632.0 79.80 SEAL ASSY BAKER Seal Assembly 3.890 I Casing Description IOD(in) IID(in) Top(ftKB) I Set Depth(ftKB) ISet Depth(ND)...IWt/Len(I...IGrade ITopThread B LINER HH 41/2 3.688 5,0461 5,2960 3,648.4 11.60 L-80 Liner Details (111I Nominal . Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,046.1 3,604.0 78.67 HANGER Baker Model 91 Hook Hanger-above 4.500 0 _ 5,062.9 3,607.3 78.58'HANGER Baker Model B1 Hook hanger-below 4.500 't 'i 5,118.4 3,618.4 78.27 ECP Baker Payzone External Csg PKR 4.500 Casing Description •OD(in) IID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WOLen(I...Grade Top Thread B LINER LEM;4,836.9-5,191.6 I A LINER Slotted 41/2 3.476 5,149.7 10,040.4 3.746.2 11.60 L-80 Buttress Liner Details Nominal ID ()LINER HH;5,046.15,296.0 Top(ftKB) Top(ND)(ftKB) Top not(") Item Des Com (in) I 5,149.7 3,624.8 78.64 PACKER "HRD"Liner top packer 5.500 INTERMEDIATE;40.45.920.0 5,168.6 3,628.4 79.20 NIPPLE "RS"Packoff Seal Nipple 4.870 5,171.0 3,628.8 79.28 HANGER FlexLock Liner Hanger 5.510 5,180.4 3,630.6 79.56 SBE 190-47 Casing Seal bore extension 4.750 -- 1 _ 5,200.1 3,634.0 80.15 XO BUSHING Cross Over Bushing 3.930 9,993.7 3,745.8 89.36 ECP Swell Packer Rubber Element 3.476 - Tubing Strings - - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 35.8 4,707.5 3,533.0 12.60 L80 IBT-mod ( Completion Details Nominal ID ( Top(ftKB) Top(ND)(ftKB) Top Incl 0) Item Des Com (in) 35.8 HANGER VETCO GRAY TUBING HANGER,Drifted 3.885" 3.900 515.9 513.6 12.36 NIPPLE CAMCO DB Nipple 3.875"NO GO PROFILE 3.875 4,631.5 3,510.8 71.27 SLEEVE-C BAKER MODEL CMU.Profile 3.812"CAMCO"DB". 3.812 - - (CLOSED 10/20/2006) 4,679.1 3,525.3 73.50 LOCATOR LOCATOR 3.990 4,680.8 3,525.8 73.60 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY:Size 192-47. 3.880 SLOTS;5.523.0-9.997.0 i _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Incl - Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) 4,631.0 3,510.7 71.25 ISO SLEEVE SET ISO SLEEVE ACROSS SLEEVE AT 4631' 9/2/2015 2.250 - - 4,730.0 3,538.6 7627 ISO SLEEVE TYPE II ISO SLEEVE IN D SAND LAT 6/9/2015 2.500 - - 5,047.0 3,604.1 78.66 TYPE I TYPE I DIVERTER IN B SAND LAT 6/9/2015 3.000 DIVERTER - - 5,049.8 3,604.7 78.65 PLUG 3.652"DB PLUG W/PRONG AND FISH NECK 6/8/2015 0.000 PROFILE A LINER Slotted;5,149.7- 10,040.41 E KUP INJ 1J-102 ConocoPhillips A)aska.Inc. Covick4 vlhps 11-102,9/13/2015 3'.22.33 PM Venical schematic(actual) .............................HANGER;35.8..,. IJ1 Perforations&Slots 'I'll � ' 4„,,,4„,,, Shot � IIa Top(ND) Btm(NDens D) (shotsM Top((tKB) Btm(ftKB) (1/KB) (f/KB) Zone Date t) Type Com .MI CONDUCTOR'40.0-1200 5,923.0 9,987.0 3,741.5 3,745.7 WS A2,WS 9/10/2006 32.0 SLOTS All Perfs in this well: NIPPLE;515.9 = A3,1J-102 Alternating solid/slotted I pipe-0.125"x2.5"@ 4 circumferential adjacent SURFACE,42.5-2,6428-.. rows,3"centers staggered 18 degrees,3' GAS LIFT,2,789.2 non-slotted ends GAS LIFT,4.a86.a Mandrel Inserts st ISO SLEEVE',4.631 0, Sati SLEEVE C,4,631.4 : ) on Top(ND) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) _ (psi) Run Date Corn i ❑ 1 2,789.2 2,362.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2006 LOCATOR;4,679.1 ll 2 4486.5 3,458.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/9/2015 SEAL ASSY;9,680.8 - Notes:General&Safety End Date Annotation 12/27/2007 NOTE:MULTI-LATERAL WELL: 1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 ISO SLEEVE;4,730.0 ': 7/3/2014 NOTE: EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' :11, D LINER LEM;4,672.7-4,866.2 • D LINER HH,4,727 2-4,984.9 TYPE I DIVERTER;5,047.0 PLUG,5,049.8 III) II/ iil 0 ,..3 B LINER LEM;4,836.9-5,191 6 B LINER HH;5,046.1-5.296.0 " i INTERMEDIATE;40.4-5,920.0 SLOTS;5,923.0-9,987.0 A LINER Slotted;10,045,1490.4.7-1 Li STATE OF ALASKA ALARAOIL AND GAS CONSERVATION CONIOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing l Operations Shutdown r Performed: Suspend Perforate p r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE TreatmtlVi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206-110 3.Address: 6.API Number: Stratigraphic r Service F P. O. Box 100360,Anchorage,Alaska 99510 50-029-23317-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,25662 KRU 1J-102 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11025 feet Plugs(measured) 5050 true vertical 3769 feet Junk(measured) none Effective Depth measured 10040 feet Packer(measured) 4673,4837, 5150 true vertical 3746 feet (true vertical) 3524, 3562, 3625 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120 120 SURFACE 2600 10.75 2643 2252 INTERMEDIATE 5880 7.625 5920 3741 A LINER SLOTTEI 4891 4.5 10040 3746 4 Perforation depth: Measured depth: slotted liner from 5923-9987 �� True Vertical Depth: 3742-3746 i i f.T 2 1 2015 Tubing(size,grade,MD,and ND) 4.5, L80,4708 MD, 3533 ND AOGGC Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 4673 MD and 3524 TVD PACKER-ZXP LINER TOP PACKER @ 4837 MD and 3562 TVD PACKER-'HRD' LINER TOP PACKER @ 5150 MD and 3625 TVD NIPPLE-CAMCO DB Nipple 3.875"NO GO PROFILE @ 516 MD and 514 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation _ 1000 Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations pr Exploratory r Development r Service p Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG � GINJ r SUSP r SPLUG r 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: 315-448 Contact John Peirce Cad 265-6471 Email John.W.Peirce(a�conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer SignaturePhone:265-6471 Date i tofo i1 S r Form 10-404 Revised 5/2015 f�yy� -' RBDMS uCi 2 2 2015 Submit Original Only KUP INJ • 1J-102 1 ConocoPhillips Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) c.„�,yf,lky 500292331700 WEST SAK INJ94.25 6,155.17 11,025.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-102,9/13/2015322:32 PM SSSV:NIPPLE 100 8/14/2012 Last WO: 44.29 10/4/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O lehallf 9/13/2015 ...............................HANGER 35.8.... l• • Casing Strings Musa .T-2,1 1I 1•IE�n..MMI Cas ng Descnptlon OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).. Wt/Len(I..Grade Top Thread CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ,AA1 CONDUCTOR;40.0-120.0, SURFACE 103/4 9.950 42.5 2,642.8 2,255.0 45.50 L-80 BTC NIPPLE;515.9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 40.4 5,920.0 3,741.1 2970 L-80 BTC-mod I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE;42.5-2,642.8- D LINER LEM 41/2 3.688 4,672.7 4,8662 3,567.8 12.60 L-80 IBT-mod GAS LIFT;2789.z Liner Details • Nominal ID MR Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) ME GAS LIFT;4,486.4 A 4,672.7 3,523.5 73.15 PACKER ZXP Liner Top Packer 4.940 18S SLEEVE;4.631.0 IN 4,691.7 3,528.8 74.19 SBR 109-47 Casing Seal Bore receptacle 4.750 SLEEVE-C;4.631.41 i 1441 4,711.3 3,534.0 75.26 XO Bushing XO Bushing 3.930 4,716.6 3,535.3 75.54 HANGER LEM Above Hook Hanger 3.668 71 4,727.2 3,537.9 76.12 HANGER LEM Below Hook Hanger 3.688 LOCATOR;4.679.1 SEAL ASSY;080.8 4,862.9 3,567.1 77.80 SEAL Seal Assembly 4.000 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len p...Grade Top Thread D LINER HH 4 1/2 3.688 4,727.2 4,984.9 3,591.9 11.60 L-80 Buttress Liner Details ISO SLEEVE;4,730.0 gx� Nominal ID :r;r; Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) �) 4,727.2 3,537.9 76.12 HANGER FLANGED HOOK HANGER 3.990 4,744.0 3,541.8 77.03 HANGER FLANGED HOOK HANGER 3.990 at 4,802.5 3,554.2 77.79 ECP PAYZONE EXTERNAL CASING PACKER 3.950 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B LINER LEM 4 1/2 3.563 4,836.9 5,191.6 3,632.6 12.75 L-80 Liner Details Nominal ID : -` Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Corn (in) D LINER LEM;A672.748662 tar. 4,836.9 3,561.5 77.72 PACKER ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 109-47 Casing Seal Bore receptacle 4.750 D LINER HH;4,727,2-4,984.9 '� 4,875.7 3,569.8 77.91 XO Bushing XO Bushing 4.500 5,036.4 3,602.1 78.69 HANGER LEM Above Hook Hanger 3.958 5,047.1 3,604.2 78.66 HANGER LEM Below Hook Hanger 3.958 TYPE I DIVERTER;5,047.0 5,081.4 3,611.0 78.47 NIPPLE CAMCO"DB"Nipple 3.563 PLUG;5,049.85,188.41 3,632.01 79.801 SEAL ASSY BAKER Seal Assembly 3.890 �i'i l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B LINER HH 4 1/2 3.688 5,046.1 5,296.0 3,648.4 11.60 L-80 Liner Details Nominal Top(ftKB) Top(ND)(ftKB) Top Incl(I Item Des Com (in) 5,046.1 3,604.0 78.67 HANGER Baker Model 81 Hook Hanger-above 4.5050 0 5,062.9 3,607.3 78.58 HANGER .Baker Model B1 Hook hanger-below 4.500 F -i 5,118.4 3,618.4 78.27 ECP Baker Payzone External Csg PKR 4.500 1 B LINER LEM;4,836.9-5,191.6 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread A LINER Slotted 41/2 3.476 5,149.7 10,040.4 3,746.2 11.60 L-80 Buttress E_ Liner Details Nominal ID B LINER 811;5,046.15,296.0 Top(ftKB) Top(TVD)(ftKB) Top Inc)Cl Item Des Com (in) I 5,149.7 3,624.8 78.64 PACKER "HRD"Liner top packer 5.500 INTERMEDIATE;40.45,920.0 5,168.6 3,628.4 79.20 NIPPLE "RS"Packoff Seal Nipple 4.870 5,171.0 3,628.8 79.28 HANGER FlexLock Liner Hanger 5.510 -- 1 - 5,180.4 3,630.6 79.56 SBE 190-47 Casing Seal bore extension 4.750 - 5,200.1 3,634.0 80.15 XO BUSHING Cross Over Bushing • 3.930 9,993.7 3,745.8 89.36 ECP Swell Packer Rubber Element 3.476 - Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 35.8 4,707.5 3,533.0 12.60 L80 IBT-mod Completion Details Nominal ID - I - Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) - - 35.8 HANGER VETCO GRAY TUBING HANGER, Drifted 3.885" 3.900 - - 5159 513.6 12.36 NIPPLE CAMCO DB Nipple 3.875"NO GO PROFILE 3.875 - - 4,631.5 3,510.8 71.27 SLEEVE-C BAKER MODEL CMU.Profile 3.812"CAMCO"DB". 3.812 - - (CLOSED 10/20/2006) - - 4,679.1 3,525.3 73.50 LOCATOR LOCATOR 3.990 - - 4,680.8 3,525.8 73.60 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY:Size 192-47. 3.880 SLOTS;5,923.0-9967.0- _ Other In Hole(Wireline retrievable plugs,valves,pumps,' S)y etc.) Top(ND) Top Incl - - Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 4,631.0 3,510.7 7125 ISO SLEEVE SET ISO SLEEVE ACROSS SLEEVE AT 4631' 9/2/2015 2.250 - 4,730.0 3,538.6 76.27 ISO SLEEVE TYPE 11 ISO SLEEVE IN D SAND LAT 6/9/2015 2.500 - - 5,047.0 3,604.1 78.66 TYPE I TYPE I DIVERTER IN B SAND LAT 6/9/2015 3.000 DIVERTER - - 5,049.8 3,604.7 78.65 PLUG 3.652"DB PLUG W/PRONG AND FISH NECK 6/8/2015 0.000 PROFILE A LINER Slotted;5,149.7- 10,040.41 1 KUP INJ • 1J-102 ConocoPhillips Alaska Inc. cr..xonK» ""• 1J-102,9/13/2015 3:22:33 PM Vertical schematic(actual) ................................HANGER;35.8.... PITO Perforations&Slots 1411-5 Shot Dens Top(ND) Btm(ND) (shots/f � Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com MI CONDUCTOR;40.0-120.0 5,923.0 9,987.0 3,741.5 3,745.7 WS A2,WS 9/10/2006 32.0 SLOTS All Perfs in this well: NIPPLE;515.91 A3,1J-102 Alternating solid/slotted I (I pipe-0.125"x2.5"@ 4 SURFACE;42.5-2,642.8- t rows, 3"en terncial adjacent rows,3"centers GAS LIFT;2,789.2 staggered 18 degrees,3' non-slotted ends GAS LIFT;4,486.4 Mandrel Inserts St ISO SLEEVE;4,631.01 fir' ati SLEEVE-C;4,631.4 .WI'.11 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type lin) (psi) Run Date Corn 8. D. 1 2,789.2 2,362.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2006 LOCATOR;4,679.1 2 4,486.5 3,458.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/9/2015 SEAL ASSY;4,680.6 0=u Notes:General&Safety End Date Annotation 12/27/2007 NOTE:MULTI-LATERAL WELL: 1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 ISO SLEEVE;4,730.0 7/3/2014 NOTE: EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' it D LINER LEM;4,672.7-4,866.2 D LINER HH;4,727.2-4,984.9 TYPE I DIVERTER;5,047.0 PLUG;5,049.8 /ill 1 181I II B LINER LEM;4,836.9-5,191.6 B LINER HH;5046.1-5296.0 INTERMEDIATE;40.4-5,9200 SLOTS;5,923.0.9,987.0- c� _ A LINER Slotted;5149 - 10,040..741 IIP 1J-102 WELL EVENTS SUMMARY • DATE SUMMARY 9/2/2015 FCO ice plug from 40'to 75'. Peforate MBE interval in B Lateral from 5,328'to 5,333' RKB with SLB 2 inch Powerflow HSD guns (2006FP-6SPF, EHD 0.45", 4.5" PEN). Verified ASF. Next, set a 2.25" ID ISO-Sleeve at leaky CMU @ 4,631' RKB. Well left freeze protected and shut in. Well is now ready for Crystal Seal job Pinholed coil tubing @ 2,315'while POOH no spills. Will cut coil tubing in morning. 9/8/2015 BRUSH n' FLUSH TBG TAG ISO SLEEVE @ 4631' RKB, IN PROGRESS. 9/9/2015 SET 4 1/2 HOLE FINDER/CATCHER SUB ASSEMBLY @ 4631' RKB, PULLED DV @ 4486' RKB, LOADED TBG & IA WITH INHIBITED SEAWATER & DIESEL FREEZE PROTECT, SET DV @ 4486' RKB MIT IA PASS, PULLED HOLE FINDER ASSEMBLY @ 4631' RKB. COMPLETE. 9/17/2015 INJECTIVITY TEST W/SAN PUMPEDI O BBLS@1BPM PUMPED 10 BBLS @ 2BPM PUMPED 80 BBLS @ 3BPM FREEZE PROTECT TBG W/35 BBLS DIESEL JOB COMPLETE 9/18/2015 Pumped fullbore MBE treatment per design placing -290 bbls 3% KCL/4 mil Crystal Seal slurry into formation (3795#of CS). Displaced gel with 80 bbls diesel. Well left shut in. Note: Do not put on injection or bring offset producer online until after 06:00, 9/19. 9/21/2015 Injectivity test, 40 bbls dsl down tbg @ 1 bbl/min pressured up to 200 psi,job complete 10/5/2015 FREEZE PROTECT WELL W/2 BBL METHANOL 100% DOWN F/L FOLLOWED BY 38 BBL DIESEL DOWN TBG JOB COMPLETE 10/8/2015 LOG 24 ARM CALIPER SURVEY FROM 4650' TO SURFACE. LOG CORRELATED TO TUBING DETAIL RECORD DATED 03 OCT 2006. DATA SENT TO ANCHORAGE FOR FURTHER PROCESSING. JOB COMPLETE. OF flys �‘0.4,1 \� s7 THE STATE Alaska Oil and Gas Of . L /\ SJ( /� Conservation Commission ``�. "' 1�. 1'1 X1`1 ,• tt-#- x___ __ 333 West Seventh Avenue �' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \Th- " ' Main: 907.279 1433 OFALASFax: 907.276.7542 www.aogcc.alaska gov John Peirce 5C0t4EU ,',; 0 Sr. Wells Engineer 0 ConocoPhillips Alaska, In a 0 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-102 Sundry Number: 315-448 Dear Mr. Peirce: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CW-41 i°4-t- -; Cathy P. oerster Chair DATED this 2L1.day of July, 2015 Encl. STATE OF ALASKA RECEIVED i ;KA OIL AND GAS CONSERVATION COM JON JUL 2 3 2015 APPLICATION FOR SUNDRY APPROVALS 7 jz4/!s p� 20 AAC 25.280 AC: � 1 Type of Request Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing J pecans Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Crystal Seal MBE Treatment Fi 2.Operator Name 4 Current Well Class 5 Permit to Drill Number. ConocoPhillips Alaska, Inc.• Exploratory r Development f 206-110 - 3 AddressStratigraphic I-- Service . , 6 API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-23317-00 • 7 If perforating, What 8 Well Name and Number Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p / KRU 1J-102 . ' 9 Property Designation(Lease Number) 10 Field/Pool(s) ADL 25661,25662 • Kuparuk River Field/West Sak Oil Pool . 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured) 11025 ' 3769 ' 10040' • 3746' % 5050' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120' 120' SURFACE 2600 10.75 2643' 2252' INTERMEDIATE 5880 7.625 5920' 3741' A LINER SLOTTED 4891 4.5 10040' 3746' Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) slotted liner from 5923-9988 • 3742-3746 4.5 L80 4708 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) , PACKER-ZXP LINER TOP PACKER MD=4673 TVD=3524 ' PACKER-ZXP LINER TOP PACKER MD=4837 TVD=3562 - PACKER-"HRD"LINER TOP PACKER MD=5150 TVD=3625 • NIPPLE-CAMCO DB Nipple 3 875"NO GO PROFILE MD=516 TVD=514 12 Attachments: Description Summary of Proposal p 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r ' 14 Estimated Date for Commencing Operations. 15 Well Status after proposed work 8/1/2015 OIL r WINJ r ' WDSPL r Suspended r 16 Verbal Approval. Date GAS r WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown F Abandoned r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Peirce @ 265-6471 EmailJohn W Peirce@conocophillips com Printed Name John Peirce Title Sr.Wells Engineer / Signature �J • $'..z� Phone 265-6471 Date 7/2 21 1 s Commission Use Only Sundry Number Conditions of approval Notify Commission so that a representative may witness 3 1 rj-y y c Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other Spacing Exception Required? Yes ❑ No / Subsequent Form Required /c _ 4 L; zf APPROVED BY Approved by COMMISSIONER THE COMMISSION Date. 7-2-51--/S- v7-L 7-! //er Approved application is valid for 12 m�o�nth$fr the date of approval. Submit Form and Form 10-403 Revised 5/2015 ?I �� l S achments in Duplicate ORIGINAL 7/J•3/--vRBDMS�jt M!9 - 22015 *-, s KUP INJ 1J-102 " ConocoPhillips �6- Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore APIIUWI Field Name Wellbore Status Inut(°) MD(ftKB) Act Btm(10KB) Como.IliMps 500292331700 WEST SAK INJ 94.25 6,155.17 11,025.0 ".. ^. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-102.6/11/201510:53:28 AM SSSV:NIPPLE Last WO: 44.29 10/4/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL ISO SLEEVES,SET PLUG 8 hipshkf 6/10/2015 HANGER;35.8 51.51 k--V. "' DIVERTERS Casing Strings ref,°may,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)..-WtlLen(L..Grade Top Thread II I'� CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 Welded Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread -AA-,coNdu6TOR;4b.d-t2D:9- SURFACE 103/4 9.950 42.5 2,642.8 2,255.0 45.50 L-80 BTC NIPPLE;515.9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len fl...Grade Top Thread INTERMEDIATE 7 5/8 6.875 40.4 5,920.0 3,741.1 29.70 L-80 BTC-mod I I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(L..Grade Top Thread SURFACE;42.5-2,642,8- D LINER LEM 412 3.688 4,672.7 4,866.2 3,567.8 12.60 L-80 IBT-mod Liner Details GAS LIFT;2,769.2 Nominal ID Top(ftKB) Top(Nd(° D)(ftKB) Top In ) Item Des Com (in) GAS UFT;4.486.4 � 4,672.7 3,523.5 73.15 PACKER ZXP Liner Top Packer 4.940 4,691.7 3,528.8 74.19 SBR109-47 Casing Seal Bore receptacle 4.750 SLEEVE-C;4,631.4 1 I 4,711.3 3,534.0 75.26 XO Bushing XO Bushing 1930 4,716.6 3,535.3 75.54 HANGER LEM Above Hook Hanger 3.668 LOCATOR;4,679.1 _ 4,7272 3,537.9 76.12 HANGER LEM Below Hook Hanger 3.688 SEAL ASSY;4,680.5 u 4,862.9 3,567.1 77.80 SEAL Seal Assembly 4.000 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(868) Set Depth(ND)...Wt/Len(I...Grade Top Thread PyV 0 LINER HH 4 12 3.6881 4,727.2 4,984.9 3,591.9 11.60 L-80 Buttress Il 1Liner Details ISO SLEEVE;4,730.0I#I I Nominal ID - Top(ftKB) Top(NO)(ftKB) Top Incl(°) Item Des Com (in) 4,727.2 3,537.9 76.12 HANGER FLANGED HOOK HANGER 3.990 4,744.0- 3,541.8 77.03 HANGER 'FLANGED HOOK HANGER 3.990 4,802.5 3,5542 77.79 ECP PAYZONE EXTERNAL CASING PACKER 3.950 l7 Casing Description OD(In) ID(In) "Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread B LINER LEM 412 3.563 4,836.9 5,191.6 3,632.6 12.75 L-80 Liner Details Nominal ID D LINER LEM;4,672.7-4,866.2 Top(ftKB) Top(TVD)OMB) Top Incl C) Item Des I Com (in) 4,836.9 3,561.5 77.72 PACKER ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 109-47 Casing Seal Bore receptade 4.750 D LINER HH;4.727.2-4,984.9 o 4,875.7 3,569.8 77.91 XO Bushing XO Bushing 4.500 5,036.4 3,602.1 78.69 HANGER LEM Above Hook Hanger 3.958 _ 5,047.1 3,6042 78.66 HANGER LEM Below Hook Hanger 3.958 _ TYPE I DIVERTER;5,047.0 III Ffi 5,081.4 3,611.0 78.47 NIPPLE CAMCO"DB"Nipple 3.563 PLUG;5,049.8 I0iiilli 5,188.4 3,632. 79.80 SEAL ASSY BAKER Seal Assembly 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B LINER HH 4 12 3.688 5,046.1 5,296.0 3,648.4 11.60 L-80 Liner Details Nominal ID - s■ Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) I5,046.1 3,604.0 78.67 HANGER Baker Model El Hook Hanger-above 4.500 5,062.9 3,607.3 78.58 HANGER Baker Model Bl Hook hanger-below 4.500 5,118.4 3,618.4 78.27 ECP Baker Payzone External Csg PKR 4.500 B LINER LEM;4,836.95,191.6 ,' Casing Description-(OD(In) ID(in) "Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(L..Grade Top Thread j A LINER Slotted I 4 12 3.476 5,149.7 10,040.4 3,746.2 11.60 L-80 Buttress Liner Details Nominal ID B LINER HH;5,046.15,296.0 -r-f,, Top(ftKB) Top(TVD)(ft(B) Top not(°) Item Des Com (in) I 5,149.7 3,624.8 78.64 PACKER "HRD"Liner top packer 5.500 INTERMEDIATE;40.45,920.0 5,168.6 3,628.4 79.20 NIPPLE "RS"Packoff Seal Nipple 4.870 5,171.0 3,628.8 79.28 HANGER FlexLock Liner Hanger 5.510 _ 5,180.4 3,630.6 79.56 SBE 190-47 Casing Seal bore extension 4.750 5,200.1 3,634.0 80.15 XO BUSHING Cross Over Bushing 3.930 i .- 9,993.7 3,745.8 89.36 ECP Swell Packer Rubber Element 3.476 Tubing Strings 1 1 - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(lb/ft) Grade Top Connection - I I - TUBING 4 1/2 3.958 35.8 4,707.5 3,533.0 12.60 L80 IBT-mod - i i Completion Details _ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Corn (in) - I I - 35.8 HANGER VETCO GRAY TUBING HANGER,Drifted 3.885" 3.900 - I I - 515.9 513.6 12.36 NIPPLE CAMCO DB Nipple 3.875"NO GO PROFILE 1875 4,631.5 3,510.8 71.27 SLEEVE-C BAKER MODEL CMU.Profile 3.812"CAMCO"DB". 3.812 (CLOSED 10/20/2006) lId 4,679.1 3,525.3 73.50 LOCATOR LOCATOR 3.990 1 1 - 4,680.8 3,525.8 73.60 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY:Size 192-47. 3.880 SLOTS;5,923.0-9,987.0I _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) - 1 I Top(TVD) Top Incl Top(ftKB) (ftKB) r) Des Com Run Date ID(in) - I - 4,730.0 3,538.6 76.27 ISO SLEEVE TYPE II ISO SLEEVE IND SAND LAT 6/9/2015 2.500 = ' - 5,047.0 3,604.1 78.66 TYPE I TYPE I DIVERTER IN B SAND LAT 6/92015 3.000 DIVERTER i - 5,049.8 3,604.7 78.65 PLUG 3.652"DB PLUG W/PRONG AND FISH NECK 6/8/2015 0.000 _ PROFILE -- I I -- - i j -_- - - i A LINER Slotted;5,149.7- 10,040.41 $ KUP INJ 1J-102 • ConocoPhillips Alaska,Inc ConocoPtil6ps ••• 13-102.6/11/2015 1653:30 AM Vertical schematic(actual) .............................. HANGER;35.8... Perforations&Slots �'il� uue. Shot Dens Top(TVD) Btm(TVD) (shotsft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com M�CONDUCTOR;40.C-120.0- 5,923.0 9,987.0 3,741.5 3,745.7 WS AZ WS 9/10/2006 32.0 SLOTS All Perfs in this well: NIPPLE;515.9 A3,1J-102 Alternating solid/slotted I I I pipe-0.125"112.5"@ 4 circumferencial adjacent SURFACE;42.62,642.8-- rows,3"Centers staggered 18 degrees,3' GAS LIFT;2,789.2 non-slotted ends GAS LIFT;4,406.4 - Mandrel Inserts St SLEEVE-C;4,631.4 I I ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com L, 1 2,789.2 2,362.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2006 LOCATOR;4,679.1 2 4,486.5 3,458.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2006 SEAL ASSY;4,680.8 Notes:General&Safety End Date Annotation !l 1227/2007 NOTE:MULTI-LATERAL WELL: 1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) L lII- ISO SLEEVE;4,730.0 " 'p 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 W-llllll 7/3/2014 NOTE:EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' D LINER LEM,4,67274,866.2 D LINER HH;4,727.24,984.9 ' 1 TYPE IDIVERTER;5.007.0 �I!:—'� PLUG;5,049.8 lif/ � ' 8 LINER LEM;4,836.9-5.191.6 JEt • B LINER HH;5,046.1-5.296.0 1 INTERMEDIATE;40.45,920.0 _ n _ -- i i - - i I - - I i - - 1 i - _ i I II i- - __ _ � _ I :- SLOTS,5,923.0.9687.0— i I _ - I I 1 I — - II — — II - I- ---- - I — — I _— - I A LINER Slotted;5,149.7- 10,040.41 1=1 1J-102L1 to 1J-159L1 B Sand MBE Treatment Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with laterals in West Sak A, B, & D sands. On 3/2/08, a 1J-102 MBE occurred to offset producer 1J-159. A 4/23/08 1J-102 main-bore IPROF saw all PWI entering 1J-102L1. A 2008 1J-102L1 IPROF RIH stuck the BHA in the B Diverter. After lengthy fishing to retrieve all of the fish, a B Iso-Sly was set 9/28/08 (before diagnosing the B MBE location). 1J-102 was on PWI to A & D sands only until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate the A lat, then a B Diverter and a D Iso-Sly were set 6/9/15. An 6/10/15 (PROF in in 1J-102L1 to 11109' MD found a robust `heel' MBE at -5350' RKB at the first slotted joint below the B LEM. Note, the top of B lat plop & drop liner is -197' out in OH lateral below the B LEM (per 9/22/06 Liner Detail). A fullbore Crystal Seal treatment to seal the B MBE is proposed to return 1E-102L1 to PWI. Procedure: E-line: 1) RIH with 5' perf gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 5328 - 5333' RKB. This perfs the middle of the first 4.5" slotted joint near the MBE at -5350' to allow better CrystalSeal entry through slotted liner to the B MBE. Fire gun. POOH. RD. Coil Tubing: 2) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv for Crystal Seal job. Perform MITIA to verify good Iso-Sly set integrity. Pumping: 3) Fullbore pump -100 bbl Step Rate Inj Test (SRIT) with Seawater to 4 bpm to verify good injectivity. Select a steady treatment rate to hold constant during Crystal Seal treatment to monitor MBE treatment response, and possible Crystal Seal screenout during slurry pumping. After SRIT, continue FB pumping Crystal Seal Slurry stages at constant rate (target 3 - 4 bpm) to the B MBE. Pump all slurry concentrations using only 4 mm mesh Crystal Seal in 3% KCL Water, starting with 0.10 ppg slurry pumped down tubing. Volume of each stage is TBD during pumping based on treating pressure responses noted during pumping. Ramp stages at: 0.10, 0.15, 0.20, to a maximum of 0.25 ppg, or (if needed) swap to pumping Flush if indication of imminent screen out develops during slurry pumping. If screenout development is noted, attempt to pump 80 bbls of Diesel Flush down tubing to displace all Crystal Seal from well to the B MBE. Tubular volume = 81 bbls (surface to MBE). If screenout has not been seen, but it is time to call Flush, pump at least 35 bbls Diesel to FP to 2000' TVD, then SD. RD. Coil Tubing: 4) RIH with 2" OD Jet Swirl Nozzle BHA (to get through 2.25" ID CMU Iso-Sly set in step 2) on either 1.5", 1.75", or 2" OD CT (best CT OD option TBD) to jet through Crystal Seal down to as deep as possible to shear and mechanically break all Crystal Seal remaining in the liner. POOH w/CT. RD. Put 1J-102L1 on PWI to evaluate results of the B MBE treatment for a period long enough to verify that a successful B MBE treatment has been achieved prior to executing step 6 and beyond. 5) RIH with Slim IPROF BHA on CT to pass through 2.25" ID CMU Iso-Sly (set in step 2). Memory log down and up passes to verify if the B MBE is sealed off or still taking PWI. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-102L1 to PWI service. If months have passed without obvious indications of a B MBE treatment failure, proceed to normal up the well to resume PWI to all 3 laterals as follows: Coil Tubing: 6) RIH & pull the 2.25" ID Iso-Sly (from leaky CMU Sleeve) at 4631' RKB. 7) RIH & pull the 'D' Iso-Sly set across the D LEM at 4730' RKB to open the D lat to PWI. 8) RIH & pull the 'B' Diverter set in the B LEM at 5047' RKB. 9) RIH & pull Prong and 3.562" Plug set at 5081' to open the A lat to PWI. 10) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv. Perform an MITIA to verify good set integrity of Iso-Sly prior to returning 1J-102 to PWI service. Return 1J-102 to PWI service to all 3 laterals. 2OCo' \\O WELL LOG TRANSMITTAL DATA LOGGED c,/ /2O15 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 2 1 201+5 RE: TMD3D Oxygen Activation Log: 1J-102 AOGCC Run Date: 5/12/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1J-102 Digital Data in DLIS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-23317-00 TMD3D Oxygen Activation Log (Processed Log) 1 Color Log 50-029-23317-00 TMD3D Oxygen Activation Log (Field print) 1 Color Log 50-029-23317-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANNECI JUN 1 2 2010 Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 13...e&det MEMORANDUM State of Alaska TO: Jim Rp -- f‘.----)1 � 7 7Ull5 Alaska Oil and Gas Conservation Commission DATE: Thursday,March 12,2015 P.I.PSupervisor 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-102 FROM: Chuck Scheve KUPARUK RIV U WSAK 1J-102 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-102 API Well Number 50-029-23317-00-00 Inspector Name: Chuck Scheve Permit Number: 206-110-0 Inspection Date: 3/5/2015 Insp Num: mitCS150306063841 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1J-102 1Type IIIW TVD 3525 . TubingT 410 410 - 410 • 410 • --- 1500 __ PTD 2061100 Type Test;SPT Test psi i- IA 1200 " 250o - 2420 - 240o • Interval14'TST JP/F P 4 OA 47 - 221 " 196 - 185 " Notes: SCANNED PIAR 312015 Thursday,March 12,2015 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, March 17, 2015 5:33 PM To: Wallace, Chris D (DOA) t —� Subject: RE: Report of IA pressure anomaly of West Sak injector 1J-102 (PTD 206-110) 11-29-13 update 12-2-14 1 '� Attachments: Picture (Device Independent Bitmap) 1jpg; 1J-102 45 day TIO plot.JPG Sorry I forgot to attach the TIO plot. NMED MAR 1 8 20\5 Well Name 1J-102 Notes: Start Date 1/3112015 Days 45 End Date 3/17/2015 2000 - WHP Annular Communication Surveillance 2E00 2000 44,*- 1E00 / .y 1000 E00 0 . Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 Feb-15 Feb-1E Mar--1E Mar--1E Mar-1E Mar-1E I o ew a :s m G e-- Jan-1E Jan-1E Feb-1E Feb-1E Feb-1E Feb-1E Feb-1E Mar-15 Mar-15 Mar-15 Mar-15 I Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 WELLS TEAM conoccPharp+ 2 From: NSK Problem Well Supv Sent: Tuesday, March 17, 2015 5:30 PM To: 'Wallace, Chris D (DOA)' Cc: Senden, R. Tyler; NSK West Sak Prod Engr; NSK Problem Well Supv Subject: RE: Report of IA pressure anomaly of West Sak injector 13-102 (PTD 206-110) 11-29-13 update 12-2-14 Chris, The 30 day injection test period has ended. The IA and OA have maintained a good differential between the two without indications of communication at this time. The well passed a witnessed MITIA on 03/05/15 as well. It is ConocoPhillips intention to return this well to normal injection. The well will continue to be monitored under normal surveillance. If there is further indication of possible communication,the well will be reported and further diagnostics done at that time. I have attached a 45 day TIO plot covering the pressure trends during the monitor period for your reference. Please let me know if you disagree. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907)659-7000 pgr. 909 « OLE Object: Picture(Device Independent Bitmap) » From: NSK Problem Well Supv Sent: Tuesday, December 02, 2014 12:50 PM To: 'Wallace, Chris D (DOA)' Cc: Senden, R. Tyler; NSK West Sak Prod Engr Subject: RE: Report of IA pressure anomaly of West Sak injector 1J-102 (PTD 206-110) 11-29-13 update 12-2-14 Chris, West Sak injector 1J-102 (PTD 206-110) had been in the process of being monitored for potential slow IA x OA communication earlier this year when an external surface casing leak developed on 1-6-14 during a diagnostic MITOA. The shallow surface casing leak was repaired in June with an external sleeve (10-404 submitted 7-1-14). Due to the open surface casing shoe,the MITOA failed. There was not enough injectivity to pump a cement shoe,so a barite pill was pumped on 11-5-14. The follow-up MITOA on 11-9-14 was then able to pass (10-404 submitted 11-10-14). The most recent passing MITIA was completed on 8/13/14. CPAI intends to return the well to water injection to continue monitoring, restarting the 30 day clock once the well comes back online. The well is overdue for its witnessed 4 yr MIT and a test will be scheduled once the well is stabilized. At the conclusion of the monitor, appropriate paperwork will be filed. Please let us know if you disagree with the plan or have any questions. « Message:WS injection well 1J-102 PTD 206-110» « File: 1J-102 90 day TIO 12-2-14.1PG » « File: MIT KRU 1J-102 non-witnessed 11-9-14.xls» « File: MIT KRU 1J-102 non-witnessed 8-13-14.xls» Brent Rogers/Kelly Lyons Problem Wells Supervisor 3 ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager (907)659-7000 pgr 909 From: NSK Problem Well Supv Sent: Friday, November 29, 2013 3:31 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK West Sak Prod Engr Subject: Report of IA pressure anomaly of West Sak injector 13-102 (PTD 206-110) 11-29-13 Chris, West Sak injector 1J-102 (PTD 206-110) has been experiencing a very slow loss of IA pressure over the last couple of months. There is now a very small differential between the IA and OA,"15psi. DHD will be performing IC-POTs today and pressuring up the IA in order to monitor the pressures to see if the phenomenon repeats itself. If there continues to be a pressure loss, additional DHD diagnostics will be performed at that time. Because the pressure loss occurred over a couple of months,the heightened-scrutiny monitor period is planned to last that long, -60 days. It will be added to the monthly report and remain there until the possible communication is either confirmed or refuted,at which point the appropriate paperwork will be filed. Please let me know if you disagree with the plan. Attached is a copy of the wellbore schematic and 90 day TIO plot. « File: 11-102 90 day TIO plot 11-29-13.jpg» « File: 1J-102 schematic.pdf» Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907)659-7000 pgr 909 4 #fir ..,-.,; ,.,:__, M -:,::.....,• .:.,: .:.,....-., y ,_.. .,.,,:-.'��,�.� ...,,...,�WFm�:.:��-.- .. • (4--;„--617---7, �\��%%i�� THE STATE A:2 a 'n-. c — — --- - 333 7v'es1 Seienth Avenue �' GOVERNOR SEAN PARNF.,.i, Anchorage, Alaska 99501 3572 _ o Ma i 907.279.1 2,3^ktuo . ALAS, 4 ZC) 4 9 -i. SatAt4E1) WAY Martin Walters Well Integrity Project ConocoPhillips Alaska, Inc. C P.O. Box 100360 1#1 (.1 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-102 Sundry Number: 314-067 Dear Mr. Walters: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this-21-ay of February, 2014. Encl. STATE OF ALASKA RECEIVED AL :A OIL AND GAS CONSERVATION COMI4h. ,ION APPLICATION FOR SUNDRY APPROVALS FEB 0 4 2014 20 AAC 25.280 (' 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change ACr Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:SC Repair Fi 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 206-110 ` 3.Address: 6.API Number: Stratigraphic r Service j✓ . P. O. Box 100360,Anchorage,Alaska 99510 50-029-23317-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No P 1 J-102 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025661,ADL0025662 • Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11025 • 3769 - Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120' 120' 520 1530 SURFACE 2600 10-3/4 2643' 2255' 5210 2480 INTERMEDIATE 5880 7-5/8 5920' 3741' 6890 4790 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5923-9987 3742-3746 4.5 L80 4679 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER GBH-22 SEAL ASSEMBLY ' MD=4681 TVD=3526 SSSV-CAMCO DB NIPPLE . MD=516 ND=514 12.Attachments: Description Summary of Proposal -pi 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Fi • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: w 5/1/2014 Oil r . Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ (N • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878@cop.com Printed Name jartin WaltJers Title: Well Integrity Project Signature r IRT---77//:'e.:-'4±1-7- Phone:659-7043 Date: 2/1/14 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\4-(Yo ( Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: p c tb 61 C u rn ,e'lit t r cp c t\1" RBDM AY u 9 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /�/ 4, 6 4. pp y0f THERO MM SYZ - 7 •A roved b COMMISSIONER THE COMMISSION Date: ISrC• Approved appli ti i v id for 12 months from the date of approval. -x/49 Z/sjlry Form 10-403(Re sed 10/2012) I NALJJ Ck f 5 Submit Form and Attachments in Duplicate VLA Z/ 5j'I 4d101/11 .4d4(0, p ConocoPh i l l i FEBps 4 2014 Alaska AOQ en P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 1, 2014 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1J-102, PTD 206-110 surface casing inspection and repair. Please contact MJ Loveland or me at 659-7043 if you have any questions. Sincerely, /71a/ ` /elZet Martin Walters ConocoPhillips Well Integrity Projects Supervisor .._...._... . ConocoPhillips Alaska,Inc. Kuparuk Well 1J-102 (PTD 206-110) SUNDRY NOTICE 10-403 APPROVAL REQUEST February 1, 2014 This application for Sundry approval for Kuparuk well 1J-102 is for the inspection and repair of a surface casing leak. During the course of performing an MITOA this well developed a surface casing leak and was subsequently report to your office on Jan 6, 2014. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s)and/or BPV. 2. Remove the floor grate,well house, flow lines,and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and build—9' cellar or excavate to less than 20' if necessary. 4. Install nitrogen purge equipment for the conductor(and OA if necessary) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform MITOA 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and/or BPV and return the well to production. 13. File 10-404 with the AOGCC post repair. Well Integrity Project Supervisor 2/1/2014 . E KUP INJ 1J-102 `- ConocoPhillips ;' ° Well Attributes Max Angle&MD TD Alaska Inc 1 x Wellbore APIIUWI Field Name Wellbore Status Incl(3 MD(ftKB) Act Btm(RKB) c,.,,,,,IRahps 500292331700 WEST SAK INJ 94.25 6,155.17 11,025.0 -•- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date- 1J-102.1/15/20141,09:08 PM SSSV:NIPPLE Last WO, 44.29 10/4/2006 Vertical schemat8 tactual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET PLUG hipshkr 1/15/2013 ...........HANGER;35.8... tit ':it a Casing Strings .. _ �,Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread "� III CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 Welded Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ft6B) Set Depth)T/D)... Wt/Len(I...Grade Top Thread ! -A-A-/CONDUCToli;4b o-120'0• ill SURFACE 103/4 9.950 42.5 2,642.8 2,255.0 45.50 L-80 BTC NIPPLE;515.9 Ilr Casing Description OD(in) ID(In) Top(RKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I.. Grade Top Thread INTERMEDIATE 75/8 6.875 40.4 5,920.0 3,741.1 29.70 L-80 BTC-mod l : I i Casing Description OD lin) ID(in) 'Top(RKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE;425-2s42n- D LINER LEM 41/2 3.688 4.672.7 4,866.2 3,567.8 12.60:L-80 IBT-mod Liner Details GAS UFT;2,789.2 r Nominal ID Top(ftKB) "Top(TVD)(MB) Top Incl(") Item Des Com (in) 4,672.73,523.5 73.15 PACKER ZXP Liner Top Packer 4.940 GAS LIFT;4,486.5 . 4,691.7' 3,528.8 74.19 SBR -109-47 Casing Seal Bore receptacle 4.750 SLEEVE-C;4,631.5, 4,711.3 3,534.0 75.26 XO Bushing XO Bushing 3.930 ISO SLEEVE-C;4,631.5• I tea^1 4,716.6 3,535.3 75.54 HANGER LEM Above Hook Hanger 3.668 I 4,727.2 3,537.9 76.12 HANGER LEM Below Hook Hanger 3.688 LOCATOR;4,679.1 - PLUG;4,685.0 4,862.9 3,567.1 77.80 SEAL Seal Assembly 4.000 SEAL ASSY;4,680.8 - ■ Casing Description OD lin) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)... WULen g...Grade Top Thread D LINER HH 41/2 3.6881 4,7272 4,984.9 3,591.9 11.60 L-80 Buttress • Liner Details I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Com lin) 4,727.2 3,537.9 76.12 HANGER FLANGED HOOK HANGER 3.990 • ' 4,744.0 3,541.8 77.03 HANGER FLANGED HOOK HANGER 3.990 4,802.5 3,554.2 77.79 ECP PAYZONE EXTERNAL CASING PACKER 3.950 Casing Description OD(in) ID lin) Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Tap Thread B LINER LEM 4 1/2 3.563 4,837.0 5,191.6 3,632.6 12.75 L-80 Liner Details Y I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (In) D LINER LEM;4,672.7.4.866.2 4,837.0 3,561.6 77.72 PACKER ZXP Liner Top Packer 5.500 4,856.1 3,565.6 77.75 SBR 109-47 Casing Seal Bore receptacle 4.750 . 4,875.8 3,569.8 77.91 XO Bushing XO Bushing 4.500 D LINER HH;4,727.2-4.984.9 5,036.5 3,602.1 78.69 HANGER LEM Above Hook Hanger 3.958 i 5,047.2 3,604.2 78.66 HANGER LEM Below Hook Hanger 3.958 ISO SLEEVE;5,049.0 5,081.4 3,611.0 78.47 NIPPLE CAMCO"DB"Nipple 3.563 5,188.4 3,632.0 79.80 SEAL ASSY BAKER Seal Assembly 3.890 Casing Description OD(in) ID(in) -Top(RKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread - B LINER HH 41/2 3.688 5,046.2 5296.0 3,648.4 11.60 L-80 I Liner Details Nominal ID Top(ftKB) Top(ND)(RKB) Top Incl(°) Item Des Com (in) 5,046.2 3,604.0 78.67 HANGER Baker Model 61 Hook Hanger-above 4.500 5,062.9 3,607.3 78.58 HANGER Baker Model 81 Hook hanger-below 4.500 Ii 11 5,118.5 3,618.4' 78.27 ECP Baker Payzone External Csg PKR 4.500 B LINER LEM;6837.0-5.191.6 Casing Description OD lin) ID(in) "Top(RKB) Set Depth(ft613) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I'--c A LINER Slotted 41/2 3.476 5,149.7 10,040.4 3,746.2 11.60 L-80 Buttress , Liner Details B LINER HH;5,046.2-5,296.0 lop(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com Nominal ID (in) 5,149.7 3,624.8 78.64 PACKER "HRD"Liner top packer 5.500 INTERMEDIATE;40.45.9200 5,168.6 3,628.4 79.20 NIPPLE "RS"Packoff Seal Nipple 4.870 5,171.0 3,628.8• 79.28 HANGER FlexLock Liner Hanger 5.510 5,180.4 3,630.6 79.56 SBE 190-47 Casing Seal bore extension 4.750 - 5,200.0 3,634.0' 80.15 XO BUSHING Cross Over Bushing 3.930 - 9,993.7 3,745.8 89.36 ECP Swell Packer Rubber Element 3.476 Tubing Strings - Tubing Description String Ma...ID(in) Top(ftKB( Set Depth(ft...Set Depth(ND)(...Wt(Iblft) Grade Top Connection IUBING 4 1/2 3.958 35.8 4,707.5 3,533.0 12.60 680 IBT-mod - Completion Details _ Nominal ID Top(ftKB) Top(ND)(fIKB) Top Incl(°) Item Des Com ('301 - tI 35.8 HANGER VETCO GRAY TUBING HANGER,Drifted 3.885" 3.900- - 515.9 513.6 12.36 NIPPLE CAMCO DB Nipple 3.875"NO GO PROFILE 3.875 - 4,631.5 3,510.8 71.27 SLEEVE-C BAKER MODEL CMU.Profile 3.812"CAMCO"DB". 3.812 i (CLOSED 10/20/2006) 4,679.1 3,525.3 73.50 LOCATOR LOCATOR 3.990 4,680.8 3,525.8 73.60 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY.Size 192-47. 3.880 _ SLOTS;6.923.09,987.0-_ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl' Top(ftKB) (RKB) p) Dec Com Run Date ID lint 4,631.5 3,510.9' 71.27 ISO SLEEVE- SET ISO SLEEVE W/DB LOCK 4'6"OAL 5/28/2009 2250 __ C - _ 4,685.0 3,527.0 73.82 PLUG 2.125"IBP INFLATABLE TO 3.88"AT 4692'RKB 1/14/2014 _ _ (OAL=11.04')SN:10464043 5,049.0 3,604.5 78.65 ISO SLEEVE B-SAND LEM ISO SLEEVE 9/27/2008 2.250 A LINER Slotted;5.149.7- 10,040.4N • • KUP INJ 1J-102 ConocoPhillips Alaska,Inc- CrarxNhdi.r. -•- 13-102,111 5/2 01 4 1:09:10 PM Vertical schematic(actual) .................... ...............HANGER;35.8... It� ..� ;ill Perforations&Slots 1111• ur /UmShot Dens Top(TVD) Btm(TVD) (sh Top(ftKB) m(ftKB) (ftKB) (ftKB) Zone Date t)t) Type Com CONDUCTOR,40.0-1io.0• 5,923.0 9,987.0 3,741.5 3,745.7 WS A2,WS 9/102006 32.0 SLOTS All Perfs in this well: NIPPLE;515.9 — A3,1J-102 Alternating solid/slotted • pipe-0.125"x2.5"@ 4 circumferencial adjacent SURFACE;42.5.2,642.8—A A rows,3"centers staggered 18 degrees,3' GAS LIFT;2,789.2 non-slotted ends GAS LIFT;4.466,5 Mandrel Inserts St SLEEVE-C;4,631.5 Alli C ISO SLEEVE-C;4,631.5, ) t«- on Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m _ 1 2,789.2 2,362.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2006 LOCATOR;4,679.1 � -� 2 4,486.5 3,458.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2006 PLUG;4.685.0 a Notes:General&Safety SEAL ASSN;4.680.8 • End Date Annotation 12/27/2007 NOTE:MULTI-LATERAL WELL: 1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 • D LINER LEM;4,672.7-4,866.2 D LINER 1-14;4,727,24984.9 - • • ISO SLEEVE;5,049.0 •• • • Oht1�1 B LINER LEM;4,637.05,191.6 .. B LINER HH;5,046.25.296.0 INTERMEDIATE;40.45,920.0 I SLOTS;5,923.0-9.9070 ,[111, A LINER Siolled.5.149.7- 10.040 4- Page 1 of 1 Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Tuesday, October 04, 2011 10:14 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV Returned to service on 1J -102 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1J -102 (PTD# 206 -110, 206 -111, 206 -112) was returned to service on 10/3/2011 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 597 psig; injection rate is 785 bwpd. This pilot had been defeated on 9/22/2011 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Jenn Gauer Work - 907.265.6782 t ,4 : — . 441 Mobile - 303.248.6641 • From: Gauer, Jenn L Sent: Thursday, September 22, 2011 5:29 PM To: CPF1 Prod Engr; 'tom.maunder @alaska.gov'; iim.regg @alaska.gov' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV defeated on 13-102 Tom and Jim The low pressure pilot (LPP) on tri- lateral injector 1J -102 (PTD# 206 -110, 206 -111, 206 -112) was defeated on 09/22/2011 when the injector was returned to service after being shut in since August 17, 2011. As of 1640 hrs on 09/22/2011, wellhead injection pressure is 485 psi; injection rate is 899 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi or the B -sand has been isolated again and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 10/4/2011 MEMORANDUM To: Jim Regg ~ ~ ~ 1~4~ P.I. Supervisor ~ ~ ( ~ I FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IJ-102 KUPARUK RIV U WSAK 1J-102 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv J~~ °F- Comm Well Name: KUPARUK RIV U WSAK 1J-102 Insp Num: mitRCN100516131605 Rel Insp Num: API Well Number: 50-029-23317-00-00 Permit Number: 206-110-0 Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IJaoz - Type Inj. ~'/ TVD 3566 / IA 990 1700 - 1680 1680 ' P.T.D 2061100 TypeTest SPT i Test psi 1700 ~ OA 165 _ 205 172 165 InteCVa14YRTST p~ P ~ Tubing 657 ~ 656 655 I 654 Notes: a1,n. fe~~~. ~~~ lscv~; k~ a<~ L. Srsvr Monday, May 24, 2010 Page 1 of 1 • ~~~. t ~~ ~.~,y ~~ :.,r~ ~ ~, ~_~ . ~w~. ~ ~.~wf. s ~.. ~4 ~. ~: MLCROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 1J DATE: OPERATOR REP: 05/14/10 Colee /Phillips - AES ~~~ ~~M . • 1 AOGCC REP: Bob Noble S ~ ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubin 657 656 655 654 Interval 4 P.T.D. 2061100 Type test P Test psi 1500 Casing 990 1,700 1,680 1,680 P/F P Notes: OA 165 205 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 Type test P Test psi 1500 Casing 1,098 1,800 1,780 1,780 P/F P Notes: OA 155 156 156 156 Well 1J-118 Type Inj. W TVD 3,599' Tubing 657 658 658 658 Interval 4 P.T.D. 2061760 Type test P Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OA 175 192 177 175 Well 1J-122 Type Inj. G TVD 3,684' Tubin 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casin 809 1,690 1,640 1,620 P/F P Notes: OA 141 214 174 156 Well 1J-127 Type Inj. W TVD 3,482' Tubing 620 620 622 622 Interval 4 P.T.D. 2060470 Type test P Test psi 1500 Casing 1,020 1,700 1,680 1,680 P/F P Notes: OA 206 273 260 253 Well 1J-136 Type Inj. N TVD 3,503' Tubing 600 600 600 600 Interval 4 P.T.D. 2061540 Type test P Test psi 1500 Casing 276 1,700 1,670 1,660 P/F P Notes: OA 173 183 182 180 Well 1J-154 Type Inj. W TVD 3,43T Tubin 624 624 624 624 Interval 4 P.T.D. 2050350 Type test P Test psi 1500 Casing 1,098 1,850 1,840 1,840 P/F P Notes: OA 527 527 527 527 Well 1J-156 Type Inj. W TVD 3,410' Tubing 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casing 1,147 1,900 1,890 1,890 P/F P Notes: OA 206 206 206 205 Well 1J-160 Type Inj. W TVD 3,212' Tubin 626 626 626 ,~ 625 Interval 4 P.T.D. 2070150 Type test P Test psi 1500 Casing 925 1,680 1,650 1,640 P/F P Notes: OA 332 333 333 334 ,,;:~.. ti MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s J V • C~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 580 578 .576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 . 1,866 1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing- 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 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 '/ V INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1J pad OS-14-10.x1s Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr (n1269@conocophillips.com] Sent: Wednesday, February 17, 2010 5:36 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Pierson, Chris R Subject: RE: LPPlSSV returned to service 1J-102 -17-Feb-2010 Tom /Jim, The low pressure pilot (LPP) on trilateral injector 1J-102 (206-110.206-111 and 206-112) was defeated on 2!11/2010 when the well was returned to injection service after being shut in for 56 days. We have now returned this LPP to service as of noon on February 17, 2010. The wellhead pressure is now 540 psig at 1250 BWPD injection. Please let me know if you have any questions. Kenneth Lloyd Kenneth Lloyd Martin/David Lloyd Lagerlef Prod. Eng. Regional AdvisorlStaff Engineer CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 Voice Page: 659-7000 pager # 765 ~~ ~Et3 ~ ~ ~~1~t 2/18/2010 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Thursday, February 11, 2010 7:28 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV defeated on 1J-102 - 11-Feb-2010 Tom /Jim, The low pressure pilot (LPP) on trilateral injector 1J-102 (206-110, 206-111 and 206-112) was defeated on 2/11/2010 when the well was returned to injection service after being shut in for 56 days. Current wellhead pressure is 327 psig; injection rate is 1200 bwpd. We expect to have the LPPs returned to service in approximately 2-3 days. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kenneth Lloyd Kenneth Lloyd Martin/David Lloyd Lagerlef Prod. Eng. Regional Advisor/Staff Engineer CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 Voice Page: 659-7000 pager # 765 2/12/2010 ~ MEMORANDUM TO: Jim Regg 7,,,`~-q P.L Supervisor ~ ~~~ 7(~`~ V ' FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-102 I{UPARUK RIV U WSAK 1J-102 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I.5uprv ~~- Comm Well Name: KUPARUK RIV U WSAK 1J-102 Insp Num: mitCS090605070725 Rel Insp Num: API Well Number: 50-029-23317-00-00 Permit Number: 206-110-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/4/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ 1J-102 Type Inj. W T~ 3566 jA 700 1950 1900 1885 1880 P.T.D 2061100 TypeTest SPT Test psi 1500 QA 170 260 215 195 180 Interval 4YRTST P~` P ~ Tubing 590 ~ 590 - 590 590 590 NOtes' Pretest pressures observed and found stable --- . -. -- 4 jf, ~' tE `)4~~{k` ~-,. l,. ~}~~.. b~k , v. f.~., ~. i.. '_ Wednesday, June 10, 2009 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION el~~ ~ ~ ZI)C~~ REPORT OF SUNDRY WELL OPERATIOI~plska 0;~ ~ Gas t:nn~ ~,,~,~._~,;, 1. operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other ~n~~a~,stall Iso sleeve Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Deve3opment ^ Expioratory ^ 206-110 3. Address: Stratigraphic ^ service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ~ 50-029-23317-00 7. I(B Elevation (ft): 9. Wel! Name and Number: RKB 121' 1J-102 8. Property Designation: 10. FieldlPool{s): ADL 25661& 25662 ' Kuparuk River Field /West Sak Oil Pool , 11. Present Well Condition Summary: Total Depth measured 11025' feet true vertical 3769' feet Plugs (measured; Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 20" 120' •~-- 120' - •~ 1,530' 520' SURFACE 10-3/4" 2,681' 2,323' 5,210' 2,480' INTERMEDIATE 7-5/8" 5,920' 3,780' 6,890' 4,790' A SAND LINER 4-1 /2" 10,040' 3,786' 7,780' 6,350' Pertoration depth: Measured depth: ~ ~ ~~.~ ,~,'c'0'ix'Y~ t.~'rv, .. ~`Jd 5923 - 9987 r:" ! ~ +~ ~f ~- true vertical depth: 3780' - 3786' Tubing (size, grade, and measured depth) 4-1/2:, L-80, 4706' (3.81" OD, 2.25" ID, CMU Isolation Sleeve at 4631') Packers &SSSV (type & measured depth) Loc Seal Assbly 4681', D-SAND LEM 4673', B-SAND LEM 4837', HRD Liner Top Packer 5150' SSSV = Camco DB Nipple 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or wA if C.O. Exempt: contact Martin Walters Printed Name Martin Walters Title Problem Wells Supervisor Signature ~ Phone: 659-7224 Date 5/31/2009 ~ l ~~ b Martin Walters 659-7224 .: ~~N ~ ~ 2Q0~ ° ~ s~' ~.G(/ ~ Ca ;.c~' Form 10-404 Revised 04!2006 ~ ~ ~ ~ ~ ~ ~ ~ S~mit OOr~yr/~/ • • 1J-102 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/24/2009 5/27/2009 ` 5/27/2009 II MITIA- failed; State witnessed (Robert Noble) Initial T/I/0= 564/880/166; Rigged up to IA with LRS and attempted to pressure up IA with no success. pumped 11.6bbls. Final T/I/0= 564/880/166 IDENTIFY LEAK @CMU 4631' RKB W/ HOLE FINDER. ATTEMPT TO CLOSE & OPEN CMU BUT UNABLE TO ENGAGE IN (BOTH DIRECTIONS) SET 4' 3" 3.82 OD, 2.60 ID, CMU ISO SLEEVE @ 4606' SLM, MIT-IA 2500# (PASS), JOB IN PROGRESS. MITIA (passed): Pre T/IA/OA = 560/2350/220, Initial T/IA/OA = 560/2500/240, 15 minute T/IA/OA = 575/2450/200, 30 minute T/IA/OA = 575/2450/200 'ULLED ISO SLEEVE FROM CMU @ 4631' RKB. BRUSH CMU @ 4631' RKB. ATTEMPT 'O OPEN CMU (UNABLE TO ENGAGE). SET 3.81" CMU ISO SLEEVE ON DB LOCK (2.83 JOGO, 2.25 MIN ID, 4' 6" LONG) @ 4631' RKB. MIT-IA 2500# (PASS), JOB COMPLETE. Packer depth questions Maunder, Thomas E (DOA) From: Fleckenstein, Robert J (DOA) Sent: Wednesday, May 27, 2009 12:06 PM To: Maunder, Thomas E (DOA) Subject: FW: Packer depth questions Page 1 of 2~ ~ Attachments: 1J-122 tvd md.jpg; 1J-102 tvd md.jpg; 1J-102 - BOT - SB TLI Schematic - Rev2.pdf; 1J-122 HBB TLI Schematic As of 06-20-2007 (With Torquemaster Packer).pdf; 1J-102.pdf; 1J-122.pdf Robert J, Fleckenstein Statisrical Technician II Alaska 4i1 and Gas Conservation Commission c~,~(' _~ ~~ Office: 907-793-1242 '`~' Fax: 907-276-7542 *Please note new email address ~ hob. fleckenstein ~ al aska.~o~: 4,'Rty~'Y M'aF> ~MfEAa/ ~` ~J Y t~= i.,.l~ ~T J From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, May 26, 2009 7:41 PM To: Fleckenstein, Robert J(DOA); Noble, Robert C(DOA}; NSK Problem Well Supv Cc: NSK Problem Well Supv Subject: Packer depth questions Bob and Bob, Ron passEd on to me that there are some discrepancies in the top packer depths for recently tested wells 1J-102 and 1 J-122. ! pu!!ed the drilling files on both wells and compared the tubing tally to our schematics and found no discrepancy between the two. I believe the schematics to be correct. 1've enclosed schematics, tubing tallies, and a screen shot of out TVD / MD converter output for both wells. I can provide the survey data if it is needed. ~~~ ~m~~ ~ -' / " ' I show the to most sealin acker on 1 J-102 to be at 4680.8 md and 3525.8 TVD. ~ p 9P I show the top most sealing packer on 1J-122 to be at 10301 and 3684.6 TVD. If you have any questions please contact the Problem wells supervisor, Martin Walters at 659-7224, or N 1617@ConocoPhillips.com c~.s~~'~" ~ ~ 8/18/2009 ~ File Edit '~iieua Fa+,~urite~ Tools H~ip 1 --- ---- ------ - ------ -- --___ _ _ _---------- - _ _ -- ------- -- --- _ _ _ ___ ~ Back - - Lx~ ~ ~ Fa~arites ~1$ Links ~] Google .~j Perry Klein WhitePages Y/ My Yahoo! ~f schematics :~~ ATDB .~j Drilling and Wells File Browser .~J Cono~oPhillips Well Events Query ~ --- _ -- -_ .: -_ _ _ _--_ _ _- Address .~f http;J/akapps.conocophillips,netJwebbert/Calculations/DepthCon~ersion/DepthConverter,aspx ~ ~ Go ~'1.~ - _ -- -- -- - - ----~.. ' --- i ConocoPhillips Pei~'oizn 11~ T'~~:'S5 UeptL C'onversions ~ Select ~~ ell ~ - ---- Field ~ KU P _ ~ BliSlllPSS WSAK ~ ~~e a: Drill Site: 1 J - ~G'ell: 1J-102 ~ bipnt Depth(s) 4680.84 ~ i Lipnt Deptl- T}1~e I C: jyID (' 'TVD r SS r CORR SS Convert - ---- _ _ _------ - - - Notes: . AI~1I'STD depths must be input as positi~•e values; S~1C~RR SS depths must be input as ueR~n~•e values. i . Separate multiple depths with white space (blanks, tabs, new lines). ',The depths may be copied to a spread sheet by highliting them and doirig a standard copy and paste. WELL NAiV~ API DPTH INPUT INPUT DPTH TYPE DFTH CORR SS DPTH NID DPTH SS DPTH TVD LAST UPDATE DATE LAST UPDATE ID X LOC Y LOC 1J-102 500292331700 4680.84 NID -3404.48 4680.84 -3404.48 3525.78 512b12009 3:01:59 PM LAEKUPG 560656.82 5945873.5 c: MEMORANDUM To: Jim Regg ~~~ SI2~~~~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-102 KUPARUK RIV U WSAK 1J-102 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~8~ Comm Well Name: KUPAItUK RIV U WSAK 1J-102 API Well Number: 50-029-23317-00-00 Insp Num: mitRCN090526111309 Permit Number: 206-110-0 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Jao2 Type Inj. W TVD 3s66 Ip 8ao P.T.D 2061100 TypeTest SPT Test psi ]soo pA ]66 Interval 4YRTST p~ F Tubing s64 NOtes: We Pumped 11.6 bbls down the IA and well did not pressure up. c P~ ~~,~~kPP/ ~p~.~-{,t SSC~,,~ CST 1 }(y/~~ L.c~~ ~_ ~ ~ zd'~ZC~ 7 3.~~~~°~~~ ~Ir ?~~~er Wednesday, May 27, 2009 Page 1 of 1 1 J-102 (PTD 206-110) Failed IA Page 1 of 1 Regg, James B (DOA) ~ ~~ _I ~ ~ From: NSK DHD Tech [n1656@conocophillips.com] Sent: Sunday, May 24, 2009 3:37 PM ~~~ ~/~ I®~j To: Regg, James B (DOA) l Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: 1J-102 (PTD 206-110) Failed MITIA Attachments: 1J-102 90 day TIO plot.png; 1J-102.pdf Jim Kuparuk Water injector 1J-102 (PTD 206-110) is suspected of havin T~ Ala due to the fluid volume pumped during the state witnessed MITIA today. The well will be shut in and freeze protected. The well will be added to the monthly report and DHD will perform diagnostics. "i Attached is the wellbore schematic and 90 day TIO plot. ..~ Please contact Problem Wells Supervisor if you have any questions. Ron Bates Lead DHD Technician Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. J «1J-102 90 day TIO plot.png» «1J-102.pdf» 5/26/2009 KRU 1J-102 PTD 206-110 5/24/2009 TIO Pressures _ _ _ ~_ -~, KUP _ _ ~OCi{7CO~f"il~~[~3$ ~ ~ ~ Well Attributes ,- , I ~ Wellbore APl/UWI Flei / 500292331700 WE ° ~ Comment H2S (ppm) Date Annotation -_ _-_ Wen co~ea -,, ~ -; AM SSSV: NIPPLE 0 7/1/2008 Last W0: S _ - - - _ Annotation Depth (RKB) End Data Annotation Last Tag: Rev Reason: SET ISO 6 } ~~: Casin~Strin~s r -. k Casing Description String 0... String ID ... Top (RKB) Set Depth (~ i CONDUCTOR 20 19.124 40.0 120.0 r- -' ~ Casing Description String 0... String ID ... Top (RKB) Set Depth (~ - i/i ... ,,....~ ( j. ,'..._. -._ SURFACE 103/4 9.950 38.4 2,680.8 40-1 Casing Description String 0... String ID ... Top (RKB) Sat Depth (' NIPPLE, 516 ~ 1 INTERMEDIATE 75/8 6.875 40.4 5,920.0 t Casing Description String 0... String ID ... lop (ttK8) Set Depth (' SURFACE, ~ ~ ~ ' BSAND WINDOW 7 3.880 5,047.0 5,057.0 3&2,681 ~ '' Casing Description String 0... String ID ... Top (RKB) Set Depth (' GAS uFT, ~-- D-SAND LEM 4 V2 3.688 4,672.7 4,8662 2,789 _ Casing Description String 0... Stdng ID ... Top (ttK8) Set Depth (' D-SAND HH 4 1/2 3.688 4,7272 4,984.9 GAS LIFT. ~ Casing Deacriptien String 0... String ID ... Top (ftK8) Set Depth (~ 4,aes _~ B-SAND LEM 4 1/2 3.563 4,837.0 5,191.6 Casing Description String 0... String ID ... Top (RKB) Set Depth (~ sLEEVE-o, -~ BSAND HH 4 1/2 3.688 5,046.2 5296.0 4,631 ` Casin Dascrl ton Stria 0... Stria ID ... To RKB Set De th w 9 pt~ 9 9 P l 1 P 1 ASAND LINER 41/2 3.476 5,149.7 10,040.4 I~ ~i~ Slotted _ _ _ --- Liner Details _ _ _ ___ I ep Dep[n (ND) Top Top (ttK8) (RKB) Incl (°) Item Description D-SAND LEM, 4,6734,866 D-SAND WINDOW, 4,937-4,947 D-SAND HH, 4,727-4.985 SLEEVE, S,Oa9 8-SAND WINDOW, 5,0475,057 ID D SAND WINDOW 4 3 880 4 937.0 4 947 0 3 625 4 Tubb StringS~ 958 . ._rr...._I p p ~ 9.. ng _. ..._ Tubing Descr pion S[ g O. Strl g ID . ITOp IttKD Set D th (t.. Set D th TVD .. Str n Wt St Gr 51 ng Top Thrd TUBING 4 1/2 I 35.8 4 /Ol 5 ~ 3 X721 ~ 12.60 L80 IBT-mod Top (RKB) I^^OI tncl (°) Item Description Comment ID (in) 35.8 35.8 -0.02 HANGER M8228, 4.909MCA top connection w/ 4.29' pup PxP, 10-3/4" x 4-1/2" Vetco 3.900 Gray Tubing Hanger Drifted 3.885, 4"H BPV, Bore 3.9" Pan #H126658-1 515.9 515.9 12.36 NIPPLE 4 1/2" Camco DB Nipple 3.875"" 3.875 4,631.5 3,550.3 70.91 SLEEVE-0 Baker Model CMU. Ran in open position. Profile 3.812" CAMCO "DB". 3.812 71ps, fi, Comment B-SAND LEM, 4,837-5,192 B-SAND HH, 5,0465,296 SLOTS, 5,923-9,987 Top (ND) Btm (ND) Top (RKB) Btm (RKB) (RKB) (RKB) 5,923.0 9,987.0 3,780.3 3,785.7 WS 1J-1 Notes: General & Safety 1 J-102 pe lna ('j ~MD tnnnt ro Imaxl tn... 12,242.0 ~ 44.29 ~ 10/4/2006 End Date IN B-SAND LEM 10/16/2008 epth (ND) ... Stang Wt.. String (sr... n[nng 7 op Th 120.0 94.00 H-40 Welded apth (ND) ... String Wt... String Or... String Top Th 2,322.6 45.50 L-80 BTC epth (ND) ... String Wt... String Gr... String Top Th 3,779.8 29.70 L-80 BTC-mod epth (ND) ... String Wt... String Gr... Skiing Top Th 3,646.1 epth (ND) ... String Wt... String Gr... String Tap Th 3,607.7 12.60 L-80 IBT-mod epth (ND) ... String Wt... String Gr... String Top Th 3,632.3 11.60 L-80 Buttress epth (ND) ... String Wt... String Gr... String Top 7h 3,672.4 12.75 L-80 eptn (ND) ... String Wt... String Gr... String Top 7h 3,688.3 11.60 L-80 epth (ND) ... String Wt... String Gr... String Top Th 3,785.8 11.60 L-80 Buttress _ __- _- _-T __ -- -- I cl ~ OD Valve Latch ~ S ze TRO Run (°) Make Model Iin1 Sarv Type Type (in) (psi) A-SAND LINER Slotted, 5,150-10,040 TD (1J-102), 11,025 • • 20" 84.0# x 34" Insulated Conductor, K-6b, set at +/. 80' 10314" x 4.112" Wellhead, 5,000 psi 10-314", 68#, BTC ~® Shoe set LID 2646' MD, 2243' ND / Tubing String 4-112" 12.6#, LAO, IBTM 3.958" ID, 3.833" Drik 5-112" X 7518" ZXP Liner ' Top Packer w/ Hold Saal Assembly Downs 4.75" Seal OD Tubing, 4-112", 12.6#, IBTM, Special Drlk to +I- 500' 3.875" DB Nipple, for Possible SSSV, +l- 500' GLM, Camco KBG-2, 4-112" X 1", 26 deg, 1,200 ft MD GLM, Camco KBG•2, 4.112" X 1", 70 deg, +/_ 1 Jt above sliding sleeve CMD Sliding Sleeve, wl 3.61" DB Nipple, 72 deg, +/. 1 Jt above seals Casing Sealbore Receptacle, 20' Length Lateral Entry Module(LEM) D-sand Window t 4865' MD, 3551' ND 4.112" 11.6# L-00 Slotkd `. Liner Swivel Liner Every Other Joint 4-112" X 7518" Seal Bores Model'B' HOOK Hanoar 3.63" ID 5-112" X 7-018" ZXP Liner Top Packer wl Hotd Downs Lateral Entrv Module (LEMI Assembly 5-112" X 7SI9" ZXP Liner Top Packer with Hold Downs Casing Sealbore Recaptack d.75" ID Orienting Proele Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation - J.68" ID ~ Access Window Poskive Laterel Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.66" ID ~\ Isolation Seal Asembly 4.75" Seal OD 3.575" Seal ID Cacing Sealbore Receptacle 20' Length Seal Assembly 4.75" Seal OD Lateral Entry MotlulelLEM) I °2 B-sand Window /at 5185' MD, 3621' ND ~~, 1` Liner Swivel 4-112" X 7SI6" Motlei'B' HOOK Hanaer Seal Bon 3.68" ID 4-112" 12.6# Tubing_____----~~ , 3.833" Dritt 3.955" ID f 5-112" X 7518" ZXP/ Liner Top Packer with Hold Downs i 5-112" X 7518" Liner Hangerl Packer Assembly at Flex Lock +1-5300'MD Liner Hanger Casing Sealbore Receptacle, 20' Length o esker Hvgnea zoos. rnla aooament may not be repredvad or mnnemea, m wnole or m pan, m any roan or by any means electronic or mechanical, Including photacopylnq, reeordlnp, or by any Information storage and retrieval system now known or hercaner Invented, wlmout written permission Irom Eater Mughef Inc. 4-112" Liner Shoe, 11.6#, L-80 BTC Set ~ 12492' MD, 3582' ND Seal Assembly 6.75" Seal OD 'A' Sand Undulating Lateral 4-112" 11.6# L-00 Sbtkd Liner Every Other Joint 4-112" Eccentric / ,Guide Shoe 7-5/8" 40# Casing, L-B0, BTC M, Set at LiD 5968' MD, 3755' ND (84 deg) Estuioment Soecifications 4-112" X 7-518" HOOK Hanger Mainbore Drlk: 5.32" Mainbore Drm, wkh diverter: 4.fi3" Lateral Drm, no diverter or LEM: 3.98" Lateral Orin, wl diverter, no LEM: 3.99" LaterellMalnbore Diverter OD: 6.75" 4-112" Lateral Entry Module Mainbore Drltt: 3.65" Mainbore Dntt, w/ isolation sleeve: 2.50" Lateral Drih, wl toll diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +1-18.5' 4-112" Casing Shoe, 11.6#, L-80 BTC Set ~ 13688' MD, 3728' ND West 88M 7419" TnJateral Completion - Inleclor July 9a, 1099 '. Drawn ey: Marc D. Kuck Re S~~NN~Ip MAY 2 S 2009 ConocoPhillips West Sak 7-5/8" Injector 1J-102 Tri-Lateral Completion 'D' Sand Lateral 3-112" Bent Joint I 3-112" Guide Shoe 4-112" Liner Shoe, 11.6#, L-80 BTC Set ~ 12187' MD, 3509' ND XKY6Nf6 Baker Oil Tools As Planned With Diverters and Isolation Lateral Access Diverter lateral Isolatbn Dlverler GS Running Tool Skiing Installed Installed (3.00" Lateral Drlkl 12.50" ID Mainbore Dritq 'GS'Protile for Coll Connecbr -' ~ RunninglRetriev rag ~ 11.00' LengM) I ~ Snap INSnap OW rBack Pressure Valve ~ a~POamve Loradrq~ (1.80' Lengthl Collet ~ Lateral laolatbn ~' ~ r Fbw-Thru Swivel I ~ Seale 11.25' Length) / HydraWk \' i ' laeral Diverter ~i, f Ramp ~ ~ Dlaconnect ~ IsoWtloN Malnbore~~~ 11.50' LengM) ~ ~ Diverter Sleeve ' ~~ GS Spear 11.50' LengM) ~ ~ L ', 1 Laeeral WWtbn ~~ ~ 6.85 tt Approx. OAL' 'B' Sand Lateral '""°°"""""""" 4-112" 11.6# L-00 Slotted Llner~ er Joln~ Bent Joint 3-112" Guide Shoe 3.562" DB Nlppk ~~ add /boa ConocoPhillips Al,iska. Inn: - -_-._ Wag tonfq- t1-~-~ HANGER, 38 CONDUCTOR,_ 60.120 NIPPLE, 518 SURFACE, 3&2 687 . GAS LIFT, ___ ___ 2,789 GAS LIFT, 4,088 SLEEVEL, I _ __ __._- 6s31 DAAND LEM, 4.8]36.866 0.SAND WINDOW, 6.93]x96] o-sAND HH. 6,]n.,ses 4 12 ells r<p ina 1'1 I tt«n IBT-mod uamL;n [op connernon w/ a.za~ Pup rxr, I u-ala- x n- u Tubing Hanger Drifted 3.885, 4"H BPV, Bore 3.9' Part B-SANO LEM, 6,83]5,192 &6AND HH, B.OIfi-5.296 rERMEDIATE, 40.8.920 sLOrs, 8.9239,98] KUP 1J-102 Well Attributes Wellbore API/UWI _ _ FMN Neme ;Maz Angle S MD _ _~ Well Sfe<u5 In<I (°) MD (ftKBI Act Bbn (Po(B) / 500292331700 WEST SAK INJ __ 11,025.0 ~ Comment HYS (ppm)Date Annota8on ' EM Dare KB-Grd (ft) Rig Release Oete ~ SSSV. NIPPLE 0 7/1!2008 ~ Las[ WO: 44.29 10/42006 I - -- _ Annotation Depth (ttKel EM Dam Annotation _ - - Last Motl BY End-Gate -- --- - - Last Tag. Rev Reason: Show SLV ~ 4631 Closed Imosbor 5/2512009 ._. __,- ~ jCasing Strings Casirg Des<riptlon . __ String 0... -String ID ... Top (ftKB) - - Set Depth (t... Set DepM (TVD) ... String WL.. String ... String Top ThM ' CONDUCTOR 20 19.124 40.0 720.0 120.0 94.00 H-40 Welded Casing Desalplion Skiing 0... •Strl1q ID ... Top (ftKB) _ ~ Set Depth (f... -Set Depth (NDI ~~~ String WL.. String ... String Top ThM i SURFACE 10314 9.950 38.4 2,680.8 2,322.6 i 45.50 L-80 BTC Casing DeuripROn Smng 0... String ID ... Top (iftcBl ~_ - _ Set Depth If... Set Depth (TVD) ... 'String WL.. Str ng - ~ String Top Thrd INTERMEDIATE 7518 6.875 40.4 5,920.0 3779.8 2970 L80 BTC-mod Casing Description Strlrg O... String lD ... Top (tncel Y -_ -_ -_ Set Depth lf....Set Depal (TVD)... String WL.. Skiing ._ Strng lop ThM 6-SAND WINDOW 7 3.880 5,047.0 5,057.0 3,646.1 ~Casirg Description String O_. ~ShIn91D ... ~TOp (ftKB) Set Depth lr... ~~Set DeDa+frVDl •~... Stri~Wt.WL ~Strhg .-~3tring Top ThM 0.SAND LEM 4 1/2 3.688 4,672.7 3,607.7 ~ 12.60 L-80 IBT-mod 4,866.2 Casing Descrip8oh String 0... ~Smng ID ... Top (ftKB) _ Sat Depth (f... Set Depth (TVDI ... 'Strirq WL.. String- String Top ThM D-SAND HH 41/2 3.688 4,727.2 4,984.9 3,632.3 11.60 '~ L-80 Buttress Lasilg Descipton Strllg O.. ~ Strmg ID ... ~ Top (ftKBI Set Depth (f ~ Set Depth (TVD) --~ Strmg WL.. String String Top ThM BSAND LEM 4 1l2 3.563 4,837.0 5 191 6 3 672 4 12 75 L 80 Casing Oesuiptlon Strmp 0... Strmg ID. Top (ftKB) ~ Set Depth (f .Set Depth (TVD) ... Str tg WL.. iStr n9 String ToP ThM I, 3 688 3 11 60 L 80 ' I casing DeacN ~~ Isms o... strbg ID ... g t rtKB ~ ( 1 Str n '9hinp Top ThM StringWL.. sat Deprh Ir.. ~~~~)~~-' 3h6~ Slott dD LINER ~ j 4112 3.476 5,149.7 l- i 3,785.8 11.60 I L-BO I Buttress 10,0404 _ -_.. _. ils Li D t .. . - nsr e a Top Depta'.. . _ . --- (NO) ' Top Intl l Top (ftKB) lttNel (°) .Item Descripton ~ Comment _-_ I ID Iinl -_ 5,149.7 3,664.2 PACKER I"HRD"Liner top packer 14.950 79.39' 5,168.6 3,668.1 i 79.78NIPPLE 'RS" Packoff Seal Nipple ~ 4.870 .~J A-SAND LINER 8bnee. 8 150-10 060 i 1 ~ ~ ;- , , TD (11102), 11,026 CI 35.8 ~2one Dafe OD ~~~ MAY 2 $ 2009 comment Sae TRO Run gM i (peg '~ Run Dots Com... FW: LPP/SSV returned to se~ on 1J-102 (PTD 206-110, 206-111,1-112) Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Monday, January 05, 2009 11:15 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Pierson, Chris R Subject: FW: LPP/SSV returned to service on 1 J-102 (PTD 206-110, 206-111, 206-112) Tom I Jim< The LPP/SSV function has been returned to normal on West Sak injector 1J-102 {PTD 206-110, 206-111, 206- 112). The well is currently injecting 1514 bwpd at 531 psi wellhead pressure Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 th; ~t ~`~ t~ ~ ~ ~~@~ ~~~~ ~ ~~u ~ X Wa From: NSK West Sak Prod Engr Sent: Sunday, September 28, 2008 8:30 AM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPFl DS Lead Techs; CPFi Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV defeated on 1]-102 Tom /Jim, The low pressure pilot (LPP) on 1J-102 (PTD 206-110, 206-111, 206-112) was defeated 9/28/2008 when the well was returned to service after being shut in for approximately 6 months. Current wellhead pressure is 181 psi, injection rate is 560 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068..001". Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 °„ +~~ ~~-.; -, ~ rr"ee A.; "~ { "jr(q~'t ATTN: Beth Well Job # Log Description 1~ i, , ~~ ~ - ( ... ~, NO. 5005 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE / - ~ 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11!17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE ]~ '^- 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE - 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL / _ 11/28/08 1 1 30-01 12097434 LDL -~ 'a- 11/29/08 1 1 1 E-04 12097436 LDL T 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE ~ 11/27/08 1 1 iH-i6 12096581 PRODUCTION PROFILE ~ 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE C -- / 12/02/08 1 1 1G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE - 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE - 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE u 12/08/08 1 1 J-102 12086701 INJECTION PROFILE - 12/14/08 1 1 i D-07 12114999 USIT -. ~ 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE _ ~ 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE _, e, 12/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. LPP/SSV defeated on 1J-102 ~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.comj Sent: Sunday, September 28, 2008 8:30 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV defeated on 1 J-102 Tom /Jim, The low pressure pilot (LPP) on 1 J-102 (PTD 206-110, 206-111, 206-112) was defeated 9/28/2008 when the well was returned to service after being shut in for approximately 6 months. Current wellhead pressure is 181 psi, injection rate is 560 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001". Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 9/29/2008 y ~a~ DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061100 Well Name/No. KUPARUK RIV U WSAK 1J-102 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23317-00-00 MD 11025 TVD 3769 Completion Date 10/4/2006 Completion Status 1-OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Iyp mearrrmi ivurnuer ryame I g Sonic Fjt~t 14215 LIS Verification apt 14215 LIS Verification ~Rpt 14215 LIS Verification pt 14215 LIS Verification D C Lis 14215 Garrnrra'R'dy S .,~,~,,,,~ fem.. ~.E'() D Asc Directional Survey D Asc Directional Survey l.~D D Asc Directional Survey D D Asc Directional Survey Log Injection Profile L Induction/Resistivity L Induction/Resistivity .fig Induction/Resistivity Log Induction/Resistivity acme meaia No Start Stop CH Received Comments 5 Col 1 2750 5120 Case 9/15/2006 USCB, USIT, GR, MaxTrac 11-Sep-2006 2606 11025 Open 11/9/2006 LIS Verification ROP, GR, FET, 2606 8159 Open 11/9/2006 P61 LIS Verification ROP, GR, FET, 2606 8350 Open 11/9/2006 PB2 LIS Verification ROP, GR, FET, 2606 9846 Open 11/9/2006 P63 LIS Verification ROP, GR, FET, 2606 11025 Open 11/9/2006 ROP, GR, FET plus PB 1, PB 2, PB 3 data 0 11025 Open 11/9/2006 0 8159 Open 11/9/2006 PB 1 0 8401 Open 11/9/2006 PB 2 0 9846 Open 11/9/2006 PB 3 2 Blu 1 4600 5300 Open 10/26/2007 Injection Profile Welltrac convey 10-Oct-2007 25 Col 120 11025 Open 3/24/2008 MD ROP, DGR, EWR 9- Sep-2006 25 Col 120 3768 Open 3/24/2008 TVD ROP, DGR, EWR 9- ', Sep-2006 25 Col 120 8159 Open 3/24/2008 P61 MD ROP, DGR, EWR 5-Sep-2006 25 Col 120 8401 Open 3/24/2008 PB2 MD ROP, DGR, EWR 6-Sep-2006 DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061100 Well Name/No. KUPARUK RIV U WSAK 1J-102 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23317-00-00 Mll 11095 TVfI 3789 Cmm~latinn flats 10/4/9008 Cmm~latinn Statue 1_(lll (:urrcnt Cta4nc 1\A/IN I ~ Ilr V r.__ _ --- - _ ___---- --- ------- - --------- ----- --- og Induction/Resistivity 25 Col 120 9846 Open 3/24/2008 P63 MD ROP, DGR, EWR 8-Sep-2006 C .- 16047 See Notes 0 0 Open 3/24/2008 1J-102 PB1 PB2 and P63 i with MD and TVD Logs in ENF, CGM, and PDF graphics ~C Lis 16047 Induction/Resistivity 2606 11025 Open 3/24/2008 LIS Veri, GR, ROP, RPD, RPS, RPM, FET, RPX, ROP ED C Lis 16047 Induction/Resistivity 2606 8159 Open 3/24/2008 P61 LIS Veri, GR,RPD, FET, RPS, RPM, RPX, ROP ED C Lis 16047 Induction/Resistivity 2606 8401 Open 3/24/2008 PB3 LIS Veri, GR,RPD, FET, RPS, RPM, RPX, ROP Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ~/ N Well Cored? Y ~N Daily History Received? Chips Received? ~`h1~J~ Formation Tops ~N Analysis / N Received? Comments: Compliance Reviewed By: ~ Date: ~,~ • • • ConocoPh i 1 I i ps _ Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ~~~-' Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1 J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1 J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1 J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1 J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1 J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1 J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1 J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 LPP/SSV defeated on 1J-102 ~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Sunday, Apri120, 2008 3:50 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1J-102 Tom /Jim, The low pressure pilot (LPP) on 1J-102 PTD 206-110, 206-111, 206-112) was defeated on 4/20/2008 when the well was returned to service after be ng s ut in since 3/2/08 (except for a short flow period on 3/31!08). Current wellhead pressure is 403 psi; injection rate is 1234 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhiliips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 4/21 /2008 Page 1 of 2 Regg, James B (DOA) ~ ~ ~~ 1 ~® From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, March 07, 2008 3:52 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 10-404 converting a well to injector without packer MD Attachments: 1 C-20. pdf; 1 J-102. pdf; 1 J-156. pdf; 1 J-170. pdf; 1 J-127. pdf; 1 J-184. pdf Jim, Here are the schematics of the motherbores fior the list of wells below. Let me know if you need any additional data or if the 10-404's need to be corrected and resubmitted. MJ Loveland ConocoPhiliips Well Integrity Project Supervisor 659-7043 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, March 03, 2008 1:58 PM To: NSK Problem Well Supv Cc: Fleckenstein, Robert J (DOA) Subject: FW: 10-404 converting a well to injector without packer MD Martin - West Sak wells have some unique approvals as you are no doubt aware. We discussed the exemption from packer requirements (20 AAC 25.200) - I am still looking into whether that is a well by well approval or some blanket authorizationlpool rule. West Sak injectors are, I believe, also completed packerless but do have a seal bore assembly and a liner top packer for the tieback string isolating the injection formation from the tubing-casing annulus. Below is a list of wells from a search of our well files that do not show a packer depth on the well completion report (10-407) or report of sundry operations {10- 404). Please provide the MD and ND of the uppermost liner top packer/seal bore assembly. Also, please remind those submitting the 404's and 407's of the uniqueness for these West Sak completions Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Fleckenstein, Robert J (DOA) Sent: Monday, March 03, 2008 1:06 PM To: Regg, James B (DOA) Subject: 10-404 converting a well to injector without packer MD Jim, The following wells have 10-404 submitted converting them from producers to injectors and have "none" or "no packer" in the packer MD data block: 2061100 WSAK 1 J-102 2060670 WSAK 1 J-156 3/12/2008 • Page 2 of 2 2060620 WSAK 1 J-170 2060470 WSAK 1J-127 2060440 WSAK 1J-184 2051230 KRU 1 C-20 BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 ~l'lease nc?t~L ~~~~~~ eciil ~a~1i~x~ess boh.fleckc:t~tc i n~ ~;alasla.~,c~`-- 3/12/2008 '~~~ KRU 1J-102 Gc~no+coi'hliips Alaska, inc. .. 1J-102 -- _ - _ -- -- _ - - -- ,.,, .j API: SuUZyZ33L/0U WeII I e: INJ An le w T5: de N SSSV T e: NIPPLE Ori Com letion: 10/4/2006 An le TD: 76 de 11025 Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE Reference Lo 40' RKB Ref Lo Date: Last U date: 1 2/2 7120 0 7 Last Ta TD: 11025 ftKB Last Tan narA Max HoIP cn~lP o7 ~I,n rn? 1n~en ~~ ~~ •~'-~ Casing String -ALL STRINGS Desr:ri tion Size To Bottom TVD Wt Grade Thread ICI I LOCATOR (4679-0680, OD:5.500) XO (10007-10010, OD:4 500) CONDUCTOR 20.000 0 140 140 62.60 H-40 WELD SURFACE 10.750 0 2682 2283 45.50 L-80 BTC INTERMEDIATE 7.625 0 5920 3741 29.70 L-80 BTCM A-SAND SLOTTED LINER 4.500 5149 10010 3746 11.60 L-80 BTCM/BTC A-SAND SLOTTED LINER 3.500 10010 10040 3746 9.30 L-80 EUE8rd Tubing String -TUBING I S¢e i Top i Bottom I TVD i Wt I Grade I Thread Perforations Summary Interval TVD Zone Status Ft SPF Date T e Comment 5923 - 9987 3741 - 3746 WS A2,WS 4064 32 9/10/2006 SLOTS Alternating solid/slotted pipe A3,WS A2, W S A3, W S A2, WS A'i WC A7 Gas Lift Mandre s/Valves ~' St MD TVD 'Man Mfr Man Type V Mfr V Type V OD Latch Puri TRO Date Run Vlv - ~`' I Cmnt 1 2789 2363 CAMCO KBMG DMY 1.0 BK-5 0.000 0 2/17/2007 ,., " 2 4486 3458 CAMCO KBMG DMY 1.0 BK-5 0.000 0 2/17/2007 Other (plugs, equip., etc.) -COMMON COMPLETION I nohrh I rvn I rho ~ - ncsr~lnrlnn I In I .. '.~ r~~~ a ~~ _' ,~,. .~ r --, -- ~• ~ _ _. ; ~; . ''a 36 36 HANGER VETCO GRAY HANGER w/4.909" MCA TOP CONNECTION 4.500 516 514 NIP CAMCO 'DB-6' NIPPLE w/NO GO PROFILE 3.875 4631 3510 SLEEVE-O BAKER 4.5" CMU SLIDING SLEEVE w/CAMCO 3.81" 'DB' PROFILE OPEN 3.812 4679 3525 LOCATOR BAKER LOCATOR GBH-22 -SPACED OUT 5.17' ABOVE FULLY INSERTED 3.990 4681 3525 SEAL BAKER 4.75" SBE SEAL ASSEMBLY 3.880 4707 3532 SHOE MULE SHOE 3.880 4937 3582 WINDOW D-SAND LINER WINDOW 3.880 1 JU4/ I 3hU4 I VVINUVVV I tr-~HNV I.INI-K VVINIJVVV I .i Xrill I Other (plugs, equip., etc.) - D-SAND & B-SAND;LEMs I nemr, I rvn I T....e I -_._,..ne~~~l.,•1.... I In i 4673 3523 PACKER D-SAND ZXP LINER TOP PACKER 4.940 4692 3528 SBR D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 4711 3533 XO Bushin D-SAND CROSSOVER BUSHING 3.930 4717 3534 HANGER D-SAND LEM ABOVE HOOK HANGER 3.688 4727 3537 HANGER D-SAND LEM INSIDE HOOK HANGER 3.688 4837 3562 PACKER B-SAND ZXP LINER TOP PACKER 4.940 4856 3566 SBR B-SAND 109-47 CASING SEAL BORE RECEPTACLE 4.750 4863 3567 SEAL D-SAND BAKER SEAL ASSEMBLY 4.000 4876 3570 XO Bushin B-SAND CROSSOVER BUSHING 3.930 5036 3602 HANGER B-SAND BAKER LEM ABOVE HOOK HANGER 3.688 I JV4/ I JO V4 I WHIN I~CK Itl-JHIVU tlHIICK IVIVUCI r5-I INJIUC r'IV VN I'1HIVl~CK _. - .-. Other (plugs, equip., etc.) - A-SAND LINER DETAIL (Undulating Liner) De th TVD T e Descri tion I .S. hlStS ) ID 5150 3624 PACKER A-SAND HRD ZXP LINER TOP PACKER 4.940 5169 3628 NIP A-SAND'RS' PACKOFF SEAL NIPPLE 4.870 5171 3628 HANGER A-SAND FLEXLOCK LINER HANGER 5.500 5180 3630 SBE A-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 5200 3634 XO Bushin A-SAND CROSSOVER BUSHING 3.930 9994 3746 PACKER A-SAND 4.5" SWELL PACKER 3.960 _10nn7 37x6 xn General Notes Date Note A-SAND CRpggnVFR 4 5" Tn 3 5" i INFR 3 5M 10/6/2006 NOTE: MULTI-LATE RAL WELL: 1J-102 (A-SAND). 1J-102L1 (B-SAND). 1J-102L2 (D-SAND1 10/25/07 ~ct~fam~er~r Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth I,~ .. N0.4468 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Well Job # Log Description Date BL Kuparuk Color CD 2N-327 11839673 PERF/SBHP p 10/24/07 1 2T-201 (REPLACES 11839656 INJECTION PROFILE ~C ( - 09/03/07 1 1A-23 11837520 PRODUCTION PROFILE q i - 10!04/07 1 2M-09A 11846446 WFL ~C - 10104107 1 31-08 11837517 LDL - 10102107 1 2M-24 11839670 PRODUCTION PROFILE 10/03/07 1 1J-102 11846451 INJECTION PROFILE U-]rC - 10/10/07 1 1Y-02 11837516 INJECTION PROFILE - 10/01/07 1 1E-112 11846450 INJECTION PROFILE 10110/07 1 2T-12A 11839669 LDL 10/02107 1 2B-07 11837522 INJECTION PROFILE (,~-L+ ~ 10/05/07 1 1E-12 11846447 DDL - 10/08/07 1 2N-327 11839671 SCMT 10/23/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. a3 Ll l / VV.• V.VIVKLVaa v1a ii/ a 1u~~ vr~ a.. ar. ~ av v .~ ~.. ~.. .~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-180 _.O Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPFl DS Lead Techs; CPFi Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, 1J-102, iJ-127, i]-164, 1J-180 Tom ;Jim, The LPPISSN's on all of the West Sak DS1 E and DS1 J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I wasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as well so I included both. WELL ID Permit to Drill No. 1 E-112 204-091 (MAINBORE), 204-092 (L1), 204-093 (L2} --~ 1J-102 206-110 (MAiNBORE), 206-111 (!1), 206-112 (L2) 1J-105 207-027 (MAINBORE), 207-028 (L1}, 207-029 (L2) 1J-127 206-047 (MAINBORE), 206-048 (L1}, 206-049 (L2) 1J-160 207-015 (MAINBORE), 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAINBORE}, 205-145 (L1}, 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these we{Is was sent 7/9/2007}. Let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Pete Nezaticky /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907} 659-7749 Email: n1638@ConocoPhitlips.com 8/27/2007 LI"i"/J~J V UCLCilLCU Vll 1D°11G~1VG~ 1J-iG/~ 1J-1V't~ 1J-lOV ~ i'il~'G 1 Vl 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.comJ Sent: Wednesday, August 15, 2007 2:01 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: LPP/SSV defeated on 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-18Q-- ~O ~ °" t~~ Tom /Jim, ~ ~~~~~~""~~ ~-- 10 5 - ~ ~i~-1 The Low Pressure Pilots (LPP) for Wesi Sak Water Injectors 1 E-112, 1 J-102, 1 J-127, 1 J-164, and 1 J-180 were defeated because of low wellhead injection pressure. These wells were shut in far a few days starting August 9 (CPF1 ESD1Coaleseer shut down), allowing bottom hose pressure to fail off. The LPPs and SSVs have been lagged and their status is recorded in the "Facility Defeated Safety Device Log." We expect the bottom hole pressures to build backup in a few days. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPPISSV function is returned to normal, in accordance ~,vith "Administrative Approval No. CO 406B.001." Please let me know if you have any questions or concerns. Regards, Hai Hunt Hai Hunt /Eric Hollar !Pete Nezaticky NSi{ West Sak Production Engineer ConocoPhi{lips Alaska, inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638a~ConocoPhiliips.com 8/16/2007 Page 1 of ~ ~ _--_ Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Tuesday, June 12, 2007 2:15 PM To: Thomas Maunder Subject: RE: Notification of LPP Defeat on West Sak Pre-Produced Injectors ~O~- ~ ~ t~ Tom, ~ The only West Sak wells that have defeated pilots are 1 J-136 and 1 J-180. The LPP on 1 J-102 and 1 J-184 were activated 2 weeks ago and I was informed that you were notified at that time. If this is not the case please let me know. Regards, Peter Nezaticky / Hai Hunt ConocoPhiilips Alaska Inc. West Sak Production Engineers s . ~, ~ ~ ~~ -~ ; ;, , , r ~ Ph: 907-659-7061 "~~"'~ ~`~`i~'~"`~,~ `~.`'~~ ." ~~~" Fax: 907-659-7749 From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, June 12, 2007 1:38 PM To: NSK West Sak Prod Engr Subject: Re: Notification of LPP Defeat on West Sak Pre-Produced Injectors Pete or Hai, Do you have a listing of the WS injectors where the pilots are defeated? Thanks, Tom Maunder, PE AOGCC NSK West Sak Prod Engr wrote, On 6/11/2007 3:44 PM: Tom / Jim, This email is to notify the AOGCC that 1 J-136 and 1 J-180 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been defeated in accordance with "Administrative Approval No. CO 4066.001 ". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". Both wells required a non-adjustable choke insert on the water injection line to limit and control water injection at lower rates. Following are the current well conditions: 1J-136: Converted from pre-production to injection 06/08/2007. Injecting 1900 bwpd at 92 psi. 1J-180: Converted from pre-production to injection 06/09/2007. Injecting 1050 bwpd at 17 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. ~ ~~~~ L ~' ~.,s~ 8/18/2009 MEMORANDUM To: Jim Rego ~~~~~ ,~~ 7~ ~ P.l. Supervisor FROM: gob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 07, 2007 SUBJECT: iViechanical integrity'Tests CONOCOPHILL[PS AL~ISKA iVC I i-102 KUPARUK RN U WSAK IJ-102 Src: Inspector NON-CONFIDENTIAL Reviewed Bv: r P.l. Supru~~ Comm Well Name: KUP.4IZUK RIV U Wsatc t.r-to2 API Well Number 50-029-23317-00-00 Inspector Name: Bob noble Insp Num: ~nitxCtvo7o3o5165ooz Permit Number: zo6-110-o Inspection Date: ~»%2007 Rel Insp Num Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. -_ - - - Well ', It-loz !,TYPe Inj. w TVD 3szs IA Aso uoo Ia9o Ia9o I __ --- -- - _- ~ --- _ ------ - P.T. zo6llo0 ~TypeTest spT Test psi '' isoo OA '' Iso zoo ?oo zoo Interval ~iT~- P/F P Tubing o o o o NOteS Well was injecting water at 0 psi. Wednesday, Nlarch 07, 2007 Page I of 1 1 J-102 LPP/SSV defeated .~ Subject: 1J-102 LPP/SSV defeated • From: NSK West Sak Prod Engr <n1638@conocophillips.com> Date: Wed, 21 Feb 2007 17:02:18 -0900 ~Qt~ -~,~~ '1'0: "I om Rlaundcr:" <tone_maundcr@admin.statc.al:.us-~. ~~ lira Re~~~~:" =jim_ re~gr~radnlin.state.ak.us-= CC: CPFI DS Lead Techs ~~=n1 140rci:~conocophillips.com~-~, CP1~ 1 Prc~~i Surat -nl 13"?@eonoeophillip~.com:>. NSI{ West Sak Prod En~r ~:n16;S(<<!conocophilli~~s.com==, "Rod~~ers. James T" <James.-C. Rod~ers~~rconocophi f11~s.com> Tam l Jim, The Low Pressure Pilot {LPP} far West Sak Water Injector 1J-102 was defeated an 20-Feb-2007 (injection startup) because of low wellhead injection pressure. 1J-102 was recently converted from pre-production to water injection service. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." This notification is in accordance with ''Administrative Approval No. CCU 4066.001." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPPISSV function is returned to normal. 1J-102 is currently taking 2134 bwpd at 2 psig wellhead injection pressure. Please let me knew if you have any questions or concerns. Regards, Hai Hai Hunt /Pete Nezaticky NSK iftlest Sak Production Engineer ConocaPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: {907} 659-7749 Email: n1638ConocoPhillips.com 1 of 1 2/22/2007 7:56 AM SARAH PALlN, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASIC~ 99501-3539 PHONE (907) 274-1433 FAX (907) 276-75423 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 ~ Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, IJ-102 Sundry Number: 306-379 Dear Mr. Buchholz: 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 Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this day of December, 2006 Encl. a~~ ~ ~cn ~' ~ ~Z~IZI ~ RECEIVE a STATE OF ALASKA ~ ~ W`' ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SEC U ~ 206 APPLICATION FOR SUNDRY APPROVALA~aska Oil & Gas Cons. Commission 20 AAC 25.280 AOChnrane 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Producer to _ Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhjllips Alaska, Inc. Development ^~ . Exploratory ^ 206-110 ~`~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: ~ P. O. Box 100360, Anchora e, Alaska 99510 50-029-23317-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership chan ges: Spacing Exception Required? YeS ^ NO ^~ 1J-102 9. Property Designation: 10. KB Elevation (ft): 11. FieldlPool(s): ADL 25661 & 25662 RKB 121' ' Kuparuk River Field /West Sak Oil Pool ' 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs-(measured): Junk (measured): 11025' 3769' - 10040' ' 3746' ' Casing Length Size MD TVD Burst Collapse .CONDUCTOR 140' 20" 140' 140' SURFACE 2521' 10-3/4" 2642' 2254' INTERMEDIATE 7-5/8" 5920' 3741' A-SAND LINER 4861' 4-1/2" 10010' 3746' A-SAND LINER 30' 3-1/2" 10040' 3746" Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 5923' - 9987' 3741' - 3746 4-1 /2" L-80 4708' Packers and SSSV Type: ~ Packers and SSSV MD (ft) SSSV= NIP SSSV= 516' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 14, 2007 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: Bob Christensen /Bob Buchholz Printed Name Robert W. B Chh IZ Title: Production Engineering Technician ~~/' Signature ~~i Phone 659-7535 Date / 2, /3 /d 6 Commission Use Onl Sundry Num ber: Conditions of approval: Notify Commission so that a representati ve may witness •~~ 3 V~ " 37 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~ C ))ppi~nee Subsequent Form Required: ~~(~~ APPROVED BY / ~ D Approved by: MISSIONER THE COMMISSION Date: ~~ ~/ ~ Form 10-403 Revised 06/2006 ~ Submit in Duplicate ~ ~r~~ 1 J-102 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-102. Plans are to pre-produce well for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-102 will provide pressure support - for the West Sak A sands. The 10-3/4" Surface casing (2642' and / 2254' tvd) was cemented with 389 bbls AS Lite followed by 76 bbls DeepCRETE. The 7-5/8" Intermediate casing (5920' and / 3741' tvd) was cemented with 350 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 4673' and / 3524' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 4837' and / 3562' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5150' and / 3625' tvd. The top of West Sak D sand was found at 4730' and / 3539' tvd. The top of West Sak B sand was found at 5047' and / 3604' tvd. The top of West Sak A sand was found at 5876' and / 3735' tvd. ~~ ~ KRU 1 J-102 - -~~ ~ I~'C:3ANICAI, INTEGRITY REPORT ~ - f _ ~ ~~~a- BUD u ^.=~ : ~~~5-y~ OPER ~ FZELD C,~~~ ~~OG~J~L - W~ =..c a~~~r..~. - ~O/~-oc~ ;,:.LL NtTMBER 1.~~-~~ a- -~--~ -`--~ .N ~ LL DAT e TD : ?~.. 'L'VD ; ? BTD : 2•ID TVD Corsi^ g : ~1 SCE Shoe : 5 3c~ ~-~~TVD t liV : ~~- ?~ ~,b. T4~i =:,e~ . Shoe . ~ T`TG ; ZCP . ?•~ ""'i~ _ moo' ~ v ~"~~'~~~1 P 2cxer ''~ TVD ; Set s t ole S~~e end '~%c.~?~=C~?, iNTEGRTTY - PART #z Perfs to - ~~ wti~~cs ~ ~~-i~~~` ~c~ , 353~i• ~~~ r_nnulus Press Test: _~ 15 nin ~0 min Comments: i '•~'CHpNZC~_I., ZNTEGR2TY - PART #Z ~--~ ~~-tl~hb~S Cement Volumes :• Amt. Liner ~ Q. Cs~ 35O s~ DV ~f~ C.~t vol to cove= oers C30Zo`~S ~~cc~~o~~`--~w~~ow9 t~q v`tc~, a ~ 0 S'1t -=:eoretical TOC ~ ~~ ~ ~S ~~~. `'C. ~~~~ . Cement Bond Log (Yes or No) -LS ; ~In`A GCC File --~ ~ S - CBL Lvzluation, zone ebove perfs Cc,K, `` ~ ~~~ i Production 'Log: Type Evaluation COI~CLJSIOt1S ?art r1 ~ ?art j2: ~ ~ ~ S Inc t Maunder, Thomas E (DOA) From: Thomas Maunder [tom maunder@admin.state.ak.us] Sent: Tuesday, December 12, 2006 11:04 AM ~~ ~~`~ To: NSK Prod Engr Tech Cc: Allsup-Drake, Sharon K Subject: Re: 1J-102, et al conversion Bob, Looking at your reply, I believe that the depths you give for the L2 window are not correct. According to the operations summary the window top is the same as the sand tops given in the same line. + Would you confirm please? ~\`~ ~~~~~ Call or message with any questions. Tom Maunder, PE ~CCK-,r~tcsa \ ~~"[~C~¢~'h( ~.}~C~ AOGCC J l r NSK $rod Engr Tech wrote, On 12/7/2006 6:16 AM: /~~ ~ >Tom, >Here's at I found: > >7-5/8" casi g: > Top = 4'md (40' tvd), Bottom = 5920' (3741' tvd), Length = 5880', >common to all wellbores. >7-5/8" casing ' dows: > 1J-102L2 To @ 4937' md (3582' tvd), D sand top found @ 4730'md (3539' > tvd ) > 1J-102L1 Top @ 047' md (3604' tvd), B sand top found @ 5047'md (3604' >tvd) > 1J-102 (Mother we bore), A sand top found @ S876' md (3735' >tvd) > >Per your suggestion, we wil start including window depths in the >"Description Summary of Prop al" page as we do not have enough room on >the 10-403 proper. > >I have forwarded your suggestion the liner top packers to Sharon >Allsup-Drake for consideration. Ap rently this question has come up in >the past. We currently provide this formation in the "Description >Summary of Proposal" page. > >Sorry for the confusion. >Bob Christensen ~~~s~~,~~~a~- ~,4~;~ ~ ~~ ~~~~ >ConocoPhillips Alaska, Inc. >Greater Kuparuk Area >Production Engineering Technician >Office (907) 659-7535 NSK-69 >Pager (907) 659-7000 (924) > > >-----Original Message----- >From: Thomas Maunder [mailto:tom maunderCadmin.state.ak. s] >Sent: Wednesday, December 06, 2006 9:04 AM >To: NSK Prod Engr Tech >Subject: 1J-102, et al conversion > > >Bob and Bob, >I am looking at the sundries for converting 1J-102 and the lateral to >injection. A couple of questions, > >1. The length of the 7-5/8" casing is listed at 5799', but the settin >depth is 5920'. There seems to be a disconnect here. Based on the RKB 1 Maunder, Thomas E (DOA) From: NSK Prod Engr Tech [n1139@conocophillips.com] Sent: Thursday, December 07, 2006 6:16 AM To: Thomas Maunder Cc: Allsup-Drake, Sharon K Subject: RE: 1J-102, et al conversion Tom, Here's what I found: 7-5/8" casing: Top = 40'md (40' tvd), Bottom = 5920' (3741' tvd), Length = 5880', common to all 3 wellbores. 7-5/8" casing Windows: 1J-102L2 Top @ 4937' md (3582' tvd), D sand top found @ 4730'md (3539' tvd) 1J-102L1 Top @ 5047' md (3604' tvd), B sand top found @ 5047'md (3604' tvd) 1J-102 (Mother wellbore), A sand top found @ 5876' md (3735' tvd) Per your suggestion, we will start including window depths in the "Description Summary of Proposal" page as we do not have enough room on the 10-403 proper. I have forwarded your suggestion on the liner top packers to Sharon Allsup-Drake for consideration. Apparently this question has come up in the past. We currently provide this information in the "Description Summary of Proposal" page. Sorry for the confusion. Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Technician ~ffice (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, December 06, 2006 9:04 AM To: NSK Prod Engr Tech Subject: 1J-102, et al conversion Bob and Bob, I am looking at the sundries for converting 1J-102 and the laterals to injection. A couple of questions, 1. The length of the 7-5/8" casing is listed at 5799', but the setting depth is 5920'. There seems to be a disconnect here. Based on the RKB height, I think the length of casing should be about 5880'. Can you reconcile? 2. According to the 407, the tvd setting depth of the 7-5/8" casing is 3741' tvd. On the -L1 403 the tvd depth is listed as 3592' and on the -L2 403 the tvd depth is listed as 3533'. According to the calculations done over here -Ll window is at 5047' md, 3604' tvd and -L2 window is at 4730' md, 3539' tvd. Are these the window tops? I know our respective depths are close. On future applications, it may make sense to have a line that lists the full intermediate casing string with another line that has the specifics of the window. What do you think? 3. On each sundry, it is indicated that there is no packer in the 1 well. While technically there isn't a packer, the LEM ZXP liner top packer at 4672' is the functional equivalent. You might check with the drilling or production engineers about the specifics. Thanks in advance for looking into these questions. I look forward to your reply. All in all, the construction looks good. The bond log is excellent. Just need to clarify these points and recommending approval should not be a problem. Tom Maunder, PE AOGCC 2 I ~RE: [Fwd: 1J-102] Subject: RE: [Fwd: 1J-102] ~' From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> '~~ Date: Wed, 15 Nov 2006 15: ~~:26 -0900 "Co: Thomas ti'~aunder <tom ~il~undcrr~i;adniin.st~te.ak.tis== CC: "Reilly, Patrick J" ~~l'atriek.J.Reill}-~"u'~;conocophillips.col~~-> We crossed a fault at +l- I {3,000 and the zone turned. vet on us. We set a swell packer at 9,993' to seal off below the swell packer. ~Il the liner below the swell packer was blank. ~~-1~-0 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, November 15, 2006 2:38 PM To: Greener, Mike R. Subject: [Fwd: 1J-102] Hi Mike, I guess Pat is not there. Can you help me? Tom ------- Original Message -------- Subject:lJ-102 Date:Wed, 15 Nov 2006 14:33:35 -0900 From:Thomas Maunder <tom maundcr~i.admn.state.ak,us=> Organization:State of Alaska To:Pat Reilly <Patrick.;l.Reillv(c~~conocopl~illips.com> CC:Steve Davies <steve clavies(cL~admin.state,ak.us> Pat, I am reviewing the 407 sent in for this well. On the motherbore were 3 PBs and the ultimate hole was drilled to 11025. The liner assembly run only went to 10040. Was there difficulty in getting further in the drilled hole or was some "call" made? I am sending this on now, but there might be other questions as I further. Tom Maunder, PE AOGCC there any review 1 of 1 11/15/2006 3:40 PM ConocoPhillips November 13, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Well Completion Reports for 1J-102, 1J-102L1 and 1J-102L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-102, 1J-102L1 and 1J- 102L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, . \ V _. R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ORIGINAL STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil a _ Gas Plugged Abandoned Suspended .WAG ^ " 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b.'Well Ctass: Development ^ , , ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: October 4, 2006 12. Permit to Drill Number: 206-110 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 25, 2006 13. API Number: 50-029-23317-00 ' 4a. Location of Well (Governmental Section): Surface: 2245' FSL, 2446' FEL, Sec. 35, T11 N, R10E, UM ' 7. Date TD Reached: September 9, 2006 14. Well Name and Number: 1J-102 At Top Productive Horizon: 872' FSL, 592' FEL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1017' FSL, 607' FEL, Sec. 2, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): - ~ 10040' MD / 3746' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558761 - y- 5946057 Zone- 4 10. Total Depth (MD + TVD): ~ 11025' MD / 3769' TVD ~ 16. Property Designation: ADL 25661 & 25662 TPI: x- 560627 y- 5944698 Zone- 4 Total Depth: x- 560657 -. - 5939565 - Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3628' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.6# H-40 40' 120' 40' 120' 42" 300 sx AS1 10.75" 45.5# L-80 40' 2643' 40' 2252' 13.5" 389 bbls AS Lite, 76 bbls DeepCRETE 7-5/8" 29.7# L-80 40' 5920' 40' 3741' 9-7/8" 350 sx DeepCRETE 4.5" 11.6# L-80 5149' 10040' 3746' 3746' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 4707 none slotted liner from 5923' to 9986' MD - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production not applicable Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (Corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". i ~- i t Rr r ir. NONE ~' ~~ F., ~vC)~l ~ `'` TOD6 ~ t ~..~,~ Form 10-407 Revised 12/2003 ~,...,~ r C t~.TJJJI~ N E ERSE ~' (~~/~ UCH 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". - ~-~, 1 J-102 West Sak A2 5876' 3735' 1J-102PB1 ` TD 8124' 3730' 1J-102P62 ~ N/A TD 8401' 3740' 1J-102PB3 TD 9846' 3750' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na d Tomas Title: Greater Kuoaruk Area Drillino Team Leader l L ~t ~~p 6 ~" Signature -- Phone '2~~ 6 ~ 3 J Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~'°~ ~ ~ ~ ~ ~' ~ I r ~ ~ r '4 ~. ~Ialliburton Company ~, Survey Report Company: ConocoPhiilips_Alaska Inc. Date: 10/16/2006 Time: 15:24:24 Pagc: 1 Field: Kuparuk RiverUnit Co-ordinatc(NE) Reference: Well: 1J-102, True North Site: Kuparuk 1J Pad Vertical{TVD) Re ference: 1J-102: 121.3 Well: 1J-102 Section (VS) Reference: Well (O.OON,O:O OE,180.OOAzi) Wellpath: 1J-102 Survey Calculation Method: Minimum Curva ture Db: Oracle Field: Kuparuk River Unit _ _ - North Slope Alaska ~ United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-102 Slot Name: Well Position: +N/-S 137.61 ft Northing: 5946057.02 ft Latitude: 70 15 47.611 N +E/-W -27.19 ft Easti ng : 558761.69 ft Longitude: 149 31 29.798 W Position Uncertainty: 0.00 ft i Wellpath: 1J-102 Drilled From: 1J-102PB3 ! 500292331700 Tie-on Depth: 9155.78 ft Current Datum: 1 J-102: Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.30 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 10/16/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 121.00 820.00 1J-102P6 869.87 7561.99 1J-102P6 1 gyro (12 1 (869.87- 1.00-820.00) 8124.27) (3) CB-GYRO-SS MWD+IFR-AK-C Camera based gyro sin AZ-SC MWD+IFR AK CAZ SC gle shot C 7600.00 9155.78 1J-102PB3 (7600.00-9812.41) (6 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 9155.78 10990.93 1 J-102 (91 55.78-10990.93) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ---- AID Licl ,azim 1'VD Sys TV'D N/S E/W VIapN MapE Tool ft deg deg ft ft ft ft ft ft 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5946057.02 ~ 558761.69 ~ TIE LINE 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 CB-GYRO-SS 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS 520.00 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS i 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+IFR-AK-CAZ-SC 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC i 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC li 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC j 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+IFR-AK-CAZ-SC 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC ', 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+IFR-AK-CAZ-SC 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 MWD+IFR-AK-CAZ-SC 2486.23 45.57 74.98 2142.53 2021.23 658.90 827.98 5946722.30 559584.42 MWD+IFR-AK-CAZ-SC ~-Ialliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Date: 10/16/2006 Time: 15:24:24 Pag_c: Z Field: Ku paruk River Unit Co-or dinate (NE} Reference: Well: 1J-10 2, TrueNorth Site: Kuparuk tJ Pad Vertical (TVD) Reference: 1J-102: 121.3 Well: 1J -102 Sectio n (VS) Reference: Well (O.OON,O. OOE,180.OOAz~ ~4'cllpath: 1J -102 __ Survey CalculationMethod: MinimumCurv ature Db: Oracle __ Survcv Mn incl Azim fVD Sys TVD N/S E,n~~ iVtapA MapE foul ft deg de g ft ft ft ft ft ft 2581 .48 43.53 80 .15 2210. 42 2089. 12 673 .33 893. 17 5946737 .23 559649 .50 MWD+IFR-AK-CAZ-SC 2602 .96 43.39 80 .76 2226. 01 2104. 71 675 .78 907. 74 5946739 .80 559664 .04 MWD+IFR-AK-CAZ-SC 2692 .50 43.33 80 .12 2291. 12 2169. 82 685 .99 968. 36 5946750 .48 559724 .58 MWD+IFR-AK-CAZ-SC 2789 .32 41.08 80 .53 2362. 83 2241. 53 696 .92 1032. 48 5946761 .91 559788 .60 MWD+IFR-AK-CAZ-SC 2883 .45 39.91 82 .89 2434. 42 2313. 12 705 .75 1092. 95 5946771 .21 559849 .00 MWD+IFR-AK-CAZ-SC 2978 .49 42.09 87 .64 2506. 16 2384. 86 710 .84 1155. 05 5946776 .78 559911 .05 MWD+IFR-AK-CAZ-SC 3072 .35 42.28 89 .81 2575. 71 2454. 41 712 .24 1218. 06 5946778 .67 559974 .04 MWD+IFR-AK-CAZ-SC 3164 .88 43.18 96 .30 2643. 71 2522. 41 708 .87 1280. 68 5946775 .79 560036 .68 MWD+IFR-AK-CAZ-SC 3260 .78 43.19 102 .29 2713. 67 2592. 37 698 .28 1345. 39 5946765 .71 560101 .46 MWD+IFR-AK-CAZ-SC ~ 3353 .79 43.31 108 .49 2781. 44 2660. 14 681 .38 1406. 77 5946749 .29 560162 .97 MWD+IFR-AK-CAZ-SC ~ 3447 .64 44.63 113 .39 2849. 00 2727. 70 658 .07 1467. 58 5946726 .46 560223 .95 MWD+IFR-AK-CAZ-SC 3541 .79 46.90 119 .91 2914. 72 2793. 42 627 .78 1527. 77 5946696 .65 560284 .36 MWD+IFR-AK-CAZ-SC 3636 I .01 48.89 126 .24 2977. 92 2856. 62 589 .62 1586. 25 5946658 .95 560343 .14 MWD+IFR-AK-CAZ-SC 3729 .21 49.70 132 .74 3038. 74 2917. 44 544 .72 1640. 70 5946614 .47 560397 .94 MWD+IFR-AK-CAZ-SC 3823 .40 49.11 138 .38 3100. 06 2978. 76 493 .70 1690. 75 5946563 .85 560448 .38 MWD+IFR-AK-CAZ-SC 3916 .77 49.70 146 .22 3160. 87 3039. 57 437 .67 1734. 03 5946508 .17 560492 .09 MWD+IFR-AK-CAZ-SC 4010 .22 51.80 150 .91 3220. 01 3098. 71 375 .94 1771. 71 5946446 .74 560530 .25 MWD+IFR-AK-CAZ-SC 4104 .27 55.02 157 .51 3276. 11 3154. 81 307 .98 1804. 45 5946379 .04 560563 .51 MWD+IFR-AK-CAZ-SC 4198 .08 57.40 161 .80 3328. 29 3206. 99 234 .90 1831. 51 5946306 .18 560591 .13 MWD+IFR-AK-CAZ-SC ~ ' 4291 .04 62.13 164 .89 3375. 10 3253. 80 157 .97 1854. 46 5946229 .45 560614 .69 MWD+IFR-AK-CAZ-SC 4384 .47 65.15 169 .96 3416. 60 3295. 30 76 .30 1872. 63 5946147 .93 560633 .49 MWD+IFR-AK-CAZ-SC 4474 .72 66.68 173 .83 3453. 44 3332. 14 -5 .25 1884. 23 5946066 .48 560645 .72 MWD+IFR-AK-CAZ-SC 4566 .87 68.47 176 .21 3488. 59 3367. 29 -90 .10 1891. 61 5945981 .70 560653 .77 MWD+IFR-AK-CAZ-SC 4664 .00 72.68 180 .95 3520. 91 3399. 61 -181 .62 1893. 83 5945890 .20 560656 .70 MWD+IFR-AK-CAZ-SC ~ 4759 .55 77.88 181 .97 3545. 18 3423. 88 -273 .97 1891. 47 5945797 .85 560655 .06 MWD+IFR-AK-CAZ-SC 4848 .85 77.69 181 .35 3564. 07 3442. 77 -361 .21 1888. 94 5945710. 60 560653 .21 MWD+IFR-AK-CAZ-SC 4942 .22 78.44 182 .65 3583. 38 3462. 08 -452 .50 1885. 75 5945619 .29 560650 .73 MWD+IFR-AK-CAZ-SC 5040 .59 78.70 180 .15 3602. 88 3481. 58 -548 .88 1883. 40 5945522 .90 560649 .13 MWD+IFR-AK-CAZ-SC 5134 .56 78.18 181 .02 3621. 71 3500. 41 -640 .94 1882. 46 5945430 .85 560648 .91 MWD+IFR-AK-CAZ-SC 5228 .52 81.01 181 .38 3638. 68 3517. 38 -733 .33 1880. 52 5945338 .46 560647 .69 MWD+IFR-AK-CAZ-SC 5322 .54 82.94 182 .32 3651. 80 3530. 50 -826 .37 1877. 51 5945245 .40 560645 .41 MWD+IFR-AK-CAZ-SC 5416 .46 81.95 180 .91 3664. 15 3542. 85 -919 .44 1874. 89 5945152 .33 .560643 .51 MWD+IFR-AK-CAZ-SC 5510 .36 81.27 181 .62 3677. 85 3556. 55 -1012 .31 1872. 84 5945059 .46 560642 .19 MWD+IFR-AK-CAZ-SC 5604. 67 80.52 182. 56 3692. 78 3571. 48 -1105 .37 1869. 44 5944966 .38 560639 .52 MWD+IFR-AK-CA2-SC 5698. 43 81.62 183 .36 3707. 33 3586. 03 -1197 .86 1864. 66 5944873. 86 560635 .46 MWD+IFR-AK-CAZ-SC 5792. 22 80.40 183 .22 3721. 99 3600. 69 -1290 .35 1859. 34 5944781. 35 560630 .87 MWD+IFR-AK-CAZ-SC 5886 .06 81.77 183 .66 3736. 53 3615. 23 -1382 .88 1853. 78 5944688. 78 560626 .02 MWD+IFR-AK-CAZ-SC 5962 .20 84.17 184 .51 3745. 85 3624. 55 -1458 .25 1848. 39 5944613 .38 560621 .23 MWD+IFR-AK-CAZ-SC 6056 .86 89.69 184 .00 3750. 92 3629. 62 -1552 .48 1841. 38 5944519 .11 560614 .96 MWD+IFR-AK-CAZ-SC 6155 .17 94.25 182 .35 3747. 54 3626. 24 -1650 .55 1835. 94 5944421 .00 560610 .28 MWD+IFR-AK-CAZ-SC 6248 .65 93.98 182 .63 3740. 83 3619. 53 -1743 .70 1831. 89 5944327 .83 560606 .96 MWD+IFR-AK-CAZ-SC 6342 .23 91.31 179 .58 3736. 51 3615. 21 -1837 .15 1830. 09 5944234 .39 560605 .89 MWD+IFR-AK-CAZ-SC 6435. 67 89.83 178 .56 3735. 58 3614. 28 -1930 .56 1831. 61 5944140 .99 560608 .13 MWD+IFR-AK-CAZ-SC 6528. 54 90.59 182 .45 3735. 24 3613. 94 -2023 .41 1830. 79 5944048. 15 560608 .04 MWD+IFR-AK-CAZ-SC 6622. 24 93.19 184 .32 3732. 15 3610. 85 -2116 .89 1825. 26 5943954. 65 560603 .24 MWD+IFR-AK-CAZ-SC 6717 .42 89.14 181 .40 3730. 21 3608. 91 -2211 .90 1820. 52 5943859. 61 560599 .24 MWD+IFR-AK-CAZ-SC i 6811 .00 88.73 180 .60 3731. 95 3610. 65 -2305 .45 1818. 88 5943766 .06 560598 .34 MWD+IFR-AK-CAZ-SC 6904 .65 90.59 182 .12 3732. 51 3611. 21 -2399 .06 1816. 66 5943672 .44 560596 .84 MWD+IFR-AK-CAZ-SC 6998 .46 89.71 179 .51 3732. 26 3610. 96 -2492 .85 1815. 33 5943578 .65 560596 .24 MWD+IFR-AK-CA2-SC 7091 .84 89.28 175 .68 3733. 09 3611. 79 -2586 .13 1819. 25 5943485 .42 560600 .89 MWD+IFR-AK-CAZ-SC 7185 .70 89.35 175 .95 3734. 21 3612. 91 -2679 .73 1826. 09 5943391 .88 560608 .47 MWD+IFR-AK-CAZ-SC 7279. 89 90.59 177. 07 3734. 26 3612. 96 -2773 .74 1831. 83 5943297. 92 560614. 93 MWD+IFR-AK-CAZ-SC ,' 7373. 81 89.03 176. 00 3734. 57 3613. 27 -2867 .49 1837. 50 5943204. 23 560621. 34 MWD+IFR-AK-CAZAZ-S ~Ialliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Uate: 10!16/2006 1'imr. 15:24:24 .Page: 3 ' Rield: Kuparuk River Unit Co-or dinate (NE) Reference: Well: 1J-10 2, T rue North ' Site: Kuparuk 1 J Pad Vertical (TVD) Reference: 1 J-102: 121.3 We1L• 1J -102 Sectio n (VS)Reference: Well (O.OON,O.OOE,180'.OOAzi) ~Yellpath: 1J -102 Survey Calculati on Method: Minimum C urvature. llb: Oracle Sun~ey ?V1D Inc! Azim TVD Sys "['VD N/S F./W biapN 1.1apE Tool ft deg deg ft ft ft ft ft ft 7468.40 89.60 178. 19 3735. 70 3614 .40 -2961 .94 1842. 30 5943109. 83 560626. 87 MWD+IFR-AK-CAZ-SC 7561.99 89.22 183. 00 3736. 66 3615 .36 -3055 .49 1841. 33 5943016. 28 560626. 63 MWD+IFR-AK-CAZ-SC 7600.00 90.05 184. 08 3736. 91 3615 .61 -3093 .43 1838. 98 5942978. 33 560624. 58 MWD+IFR-AK-CAZ-SC 7654.14 88.40 184. 13 3737. 64 3616 .34 -3147 .43 1835. 10 5942924. 31 560621. 12 MWD+IFR-AK-CAZ-SC 7751.11 91.65 183. 93 3737. 60 3616 .30 -3244 .14 1828. 29 5942827. 56 560615. 06 MWD+IFR-AK-CAZ-SC 7844.06 90.95 182. 95 3735. 49 3614 .19 -3336 .90 1822. 71 5942734. 77 560610. 21 MWD+IFR-AK-CAZ-SC 7937.60 88.53 185. 01 3735. 91 3614 .61 -3430 .20 1816. 22 5942641. 43 560604. 45 MWD+IFR-AK-CAZ-SC 8031.15 91.15 182. 05 3736. 17 3614 .87 -3523 .55 1810. 46 5942548. 04 560599. 42 MWD+IFR-AK-CAZ-SC ~ 8123.52 89.96 180. 25 3735. 28 3613. 98 -3615. 90 1808. 61 5942455. 70 560598. 29 MWD+IFR-AK-CAZ-SC 8217.41 90.40 178. 82 3734. 98 3613. 68 -3709. 78 1809. 37 5942361. 83 560599. 78 MWD+IFR-AK-CAZ-SC j 8312.47 91.02 178. 47 3733. 81 3612 .51 -3804. 81 1811. 62 5942266. 83 560602. 77 MWD+IFR-AK-CAZ-SC 8405.93 89.28 175. 82 3733. 56 3612 .26 -3898. 14 1816. 28 5942173. 55 560608. 15 MWD+IFR-AK-CAZ-SC 8500.07 90.40 174. 02 3733. 82 3612 .52 -3991 .90 1824. 61 5942079. 86 560617. 22 MWD+IFR-AK-CAZ-SC 8590.58 89.22 174. 88 3734. 12 3612 .82 -4081 .98 1833. 36 5941989. 86 560626. 68 MWD+IFR-AK-CAZ-SC 8687.42 87.18 178. 04 3737. 17 3615 .87 -4178 .57 1839. 34 5941893. 33 560633. 41 MWD+IFR-AK-CAZ-SC 8781.20 90.54 178. 71 3739. 03 3617 .73 -4272 .28 1842. 00 5941799. 65 560636. 79 MWD+IFR-AK-CAZ-SC 8874.70 90.46 178. 86 3738. 22 3616. 92 -4365. 76 1843. 98 5941706. 20 560639. 51 MWD+IFR-AK-CAZ-SC 8968.59 91.51 179. 54 3736. 60 3615. 30 -4459. 62 1845. 29 5941612. 36 560641. 55 MWD+IFR-AK-CAZ-SC 9062.10 88.03 179. 64 3736. 98 3615. 68 -4553. 12 1845. 96 5941518. 88 560642. 95 MWD+IFR-AK-CAZ-SC 9155.78 89.23 179. 02 3739. 22 3617. 92 -4646. 76 1847. 06 5941425. 26 560644. 77 MWD+IFR-AK-CAZ-SC ~ 9210.00 89.62 180. 15 3739. 76 3618 .46 -4700. 98 1847. 45 5941371. 05 560645. 59 MWD+IFR-AK-CAZ-SC ' 9249.07 86.17 179. 66 3741. 20 3619 .90 -4740 .01 1847. 51 5941332. 02 560645. 96 MWD+IFR-AK-CAZ-SC 9342.87 90.61 178. 12 3743. 83 3622 .53 -4833 .73 1849. 33 5941238. 33 560648. 51 MWD+IFR-AK-CAZ-SC 9436.84 89.96 177. 72 3743. 36 3622 .06 -4927 .64 1852. 74 5941144. 46 560652. 65 MWD+IFR-AK-CAZ-SC 9530.73 88.85 177. 20 3744. 34 3623 .04 -5021 .43 1856. 90 5941050. 72 560657. 54 MWD+IFR-AK-CAZ-SC 9624.69 89.41 179. 92 3745. 77 3624. 47 -5115. 34 1859. 26 5940956. 84 560660. 63 MWD+IFR-AK-CAZ-SC 9718.01 89.35 179. 70 3746. 78 3625. 48 -5208. 65 1859. 57 5940863. 54 560661. 67 MWD+IFR-AK-CAZ-SC 9812.24 89.97 181. 16 3747. 34 3626. 04 -5302. 88 1858. 86 5940769. 32 560661. 70 MWD+IFR-AK-CAZ-SC 9906.50 91.33 180. 22 3746. 27 3624. 97 -5397. 12 1857. 73 5940675. 08 560661. 30 MWD+IFR-AK-CAZ-SC 9997.10 89.28 179. 98 3745. 78 3624. 48 -5487. 71 1857. 57 5940584. 50 560661. 85 MWD+IFR-AK-CAZ-SC 10090.35 89.91 179. 91 3746. 44 3625. 14 -5580. 96 1857. 66 5940491. 26 560662. 67 MWD+IFR-AK-CAZ-SC ~ 10184.97 91.14 183. 10 3745. 58 3624. 28 -5675. 53 1855. 18 5940396. 68 560660. 92 MWD+IFR-AK-CAZ-SC j 10278.19 93.37 184. 92 3741. 91 3620 .61 -5768. 44 1848. 66 5940303. 73 560655. 13 MWD+IFR-AK-CAZ-SC ~ 10371.55 93.42 184. 70 3736. 38 3615. 08 -5861. 31 1840. 85 5940210. 82 560648. 05 MWD+IFR-AK-CAZ-SC 10465.93 96.34 184. 13 3728. 35 3607. 05 -5955. 06 1833. 61 5940117. 02 560641. 54 MWD+IFR-AK-CAZ-SC 10559.54 97.03 181. 18 3717. 45 3596. 15 -6047. 92 1829. 30 5940024. 14 560637. 96 MWD+IFR-AK-CAZ-SC 10652.94 91.16 177. 45 3710. 78 3589. 48 -6141. 02 1830. 43 5939931. 06 560639. 81 MWD+IFR-AK-CAZ-SC 10746.58 85.67 177. 32 3713. 37 3592. 07 -6234. 49 1834. 70 5939837. 64 560644. 80 MWD+IFR-AK-CAZ-SC 10840.35 79.38 177. 36 3725. 56 3604. 26 -6327. 31 1839. 01 5939744. 86 560649. 84 MWD+IFR-AK-CAZ-SC 10933.52 75.31 178. 02 3745. 97 3624. 67 -6418. 13 1842. 68 5939654. 08 560654. 22 MWD+IFR-AK-CAZ-SC 10990.93 75.61 178. 81 3760. 38 3639. 08 -6473. 68 1844. 21 5939598. 55 560656. 19 MWD+IFR-AK-CAZ-SC = 11025.00 75.61 178. 81 3768. 85 ~ 3647. 55 -6506. 67 1844. 90 5939565. 57 ~ 560657. 13 .PROJECTED to TD ~Ialliburton Company Survey Report Company: ConocoPhillipsAlaskalnc. Date: 10/16/2006 Timc: 14:49:43 Page: 1 Field: K uparuk River Unit Co -ordinate(NE) Reference: Well: 1J-102, True North Site: K uparuK 1J Pad Ve rtical{TVD) Re ference: 1J-102PB1: 121 .3 Well: 1J-102 Sectian (VS) Reference: Well (O.OON,0.OOE,180:OOAzi) Wellpathr 1J-102PB1 Survey Calculation Method: Minimum Curva ture Db: Oracle Field: Kuparuk River Unit -_ - - - North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1J-102 Slot Name: Well Position : +N/-S 137.61 ft North ing: 594605 7.02 ft Latitude: 70 15 47.611 N +E/-W -27.19 ft Easting : 55876 1.69 ft Longitude: 149 31 29.798 W Position Unc ertainty: 0.00 ft Wellpath: 1J-102PB1 Drilled From: Well Ref. Point 500292331770 Tie-on Depth: 40.30 ft i Current Datum: 1 J-102P61: Height 12 1.30 ft Above System Datum: Mean Sea Level Magnetic Da ta: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.30 0.00 0.00 180.00 ' Survey Program for DeSnitive Wellpath Date: 8/28/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 121.00 820.00 1J-102PB1 gyro (121.00-820.00) CB-GYRO-SS Camera based gyro single shot 869.87 8124.27 1 J-102P61 (869.87-8124.27) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey -_. biD lnci Azim TVD Sys "1'VD \;ti E/yV h1apN MapE "fool ft deg;' deg ft ft ft ft ft ft 40.30 __ 0.00 0.00 __ 40.30 -81.00 ____ 0.00 0.00 5946057.02 558761.69 _ TIE LINE 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 CB-GYRO-SS 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS ~ 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS ' 520.00 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS ~ 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+IFR-AK-CAZ-SC 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+tFR-AK-CAZ-SC 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC i 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC ' 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+iFR-AK-CAZ-SC 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 MWD+IFR-AK-CAZ-SC 2486.23 45.57 74.98 2142.53 2021.23 658.90 827.98 5946722.30 559584.42 MWD+IFR-AK-CAZ-SC 2581.48 43.53 80.15 2210.42 2089.12 673.33 893.17 5946737.23 559649.50 MWD+IFR-AK-CAZ-SC 2602.96 43.39 80.76 2226.01 2104.71 675.78 907.74 5946739.80 559664.04 MWD+IFR-AK-CAZ-SC ,~Ialliburton Company Survey Report Comp:~n~ : ConocoPhillipsAlaskainc. llate: 10/16/2006 Timc: 14:49:43 Page: ? Field: Kuparuk River tJni f Co-or dinate (NE) Reference: Well: 1J-10 2, True North Site: Kuparuk 1J Pad Vertical ('I"VD) Reference: 1J-102PB1 : 121 .3 We)1: 1J -102 Sectio n (VS) Reference: Well'(O.OON,O.OOE,180.OOAzi) Wellpath: 1J -102PB1 Survey Calc ulation Method: Minimum Curvature bb: Oracle Survev ~~ID Incl Azim TVD Sys'I'V D N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2692 .50 43.33 80 .12 2291. 12 2169. 82 685 .99 968. 36 5946750 .48 559724 .58 MWD+IFR-AK-CAZ-SC 2789 .32 41.08 80 ,53 2362. 83 2241. 53 696 .92 1032. 48 5946761 .91 559788 .60 MWD+IFR-AK-CAZ-SC i 2883 .45 39.91 82 .89 2434. 42 2313. 12 705 .75 1092. 95 5946771 .21 559849 .00 MWD+IFR-AK-CAZ-SC 2978 .49 42.09 87 .64 2506. 16 2384. 86 710 .84 1155. 05 5946776 .78 559911 .05 MWD+IFR-AK-CAZ-SC 3072 .35 42.28 89 .81 2575. 71 2454. 41 712 .24 1218. 06 5946778 .67 559974 .04 MWD+IFR-AK-CAZ-SC 3164 .88 43.18 96 .30 2643. 71 2522. 41 708 .87 1280. 68 5946775 .79 560036 .68 MWD+IFR-AK-CAZ-SC ~ 3260 .78 43.19 102 .29 2713. 67 2592. 37 698 .28 1345. 39 5946765 .71 560101 .46 MWD+tFR-AK-CAZ-SC ~ 3353 .79 43.31 108 .49 2781. 44 2660. 14 681 .38 1406. 77 5946749 .29 560162 .97 MWD+IFR-AK-CAZ-SC 3447 .64 44.63 113 .39 2849. 00 2727. 70 658 .07 1467. 58 5946726 .46 560223 .95 MWD+IFR-AK-CAZ-SC 3541 .79 46.90 119 .91 2914. 72 2793. 42 627 .78 1527. 77 5946696 .65 560284 .36 MWD+IFR-AK-CAZ-SC 3636 .01 48.89 126 .24 2977. 92 2856. 62 589 .62 1586. 25 5946658 .95 560343 .14 MWD+IFR-AK-CAZ-SC 3729 .21 49.70 132 .74 3038. 74 2917. 44 544 .72 1640. 70 5946614 .47 560397 .94 MWD+IFR-AK-CAZ-SC 3823 .40 49.11 138 .38 3100. 06 2978. 76 493 .70 1690. 75 5946563 .85 560448 .38 MWD+IFR-AK-CAZ-SC 3916 .77 49.70 146 .22 3160. 87 3039. 57 437 .67 1734. 03 5946508 .17 560492 .09 MWD+IFR-AK-CAZ-SC 4010 .22 51.80 150 .91 3220. 01 3098. 71 375 .94 1771. 71 5946446 .74 560530 .25 MWD+IFR-AK-CAZ-SC 4104 .27 55.02 157 .51 3276. 11 3154. 81 307 .98 1804. 45 5946379 .04 560563 .51 MWD+IFR-AK-CAZ-SC 4198 .08 57.40 161 .80 3328. 29 3206. 99 234 .90 1831. 51 5946306 .18 560591 .13 MWD+IFR-AK-CAZ-SC 4291 .04 62.13 164 .89 3375. 10 3253. 80 157 .97 1854. 46 5946229 .45 560614 .69 MWD+IFR-AK-CAZ-SC 4384 .47 65.15 169 .96 3416. 60 3295. 30 76 .30 1872. 63 5946147 .93 560633 .49 MWD+IFR-AK-CAZ-SC 4474 .72 66.68 173 .83 3453. 44 3332. 14 -5 .25 1884. 23 5946066 .48 560645 .72 MWD+IFR-AK-CAZ-SC 4566 .87 68.47 176 .21 3488. 59 3367. 29 -90 .10 1891. 61 5945981 .70 560653 .77 MWD+IFR-AK-CAZ-SC 4664 .00 72.68 180 .95 3520. 91 3399. 61 -181 .62 1893. 83 5945890 .20 560656 .70 MWD+IFR-AK-CAZ-SC 4759 .55 77.88 181 .97 3545. 18 3423. 88 -273 .97 1891. 47 5945797 .85 560655 .06 MWD+IFR-AK-CAZ-SC 4848 .85 77.69 181 .35 3564. 07 3442. 77 -361 .21 1888. 94 5945710 .60 560653 .21 MWD+IFR-AK-CAZ-SC 4942 .22 78.44 182 .65 3583. 38 3462. 08 -452 .50 1885. 75 5945619 .29 560650 .73 MWD+IFR-AK-CAZ-SC 5040 .59 78.70 180 .15 3602. 88 3481. 58 -548 .88 1883. 40 5945522 .90 560649 .13 MWD+IFR-AK-CAZ-SC 5134 .56 78.18 181 .02 3621. 71 3500. 41 -640 .94 1882. 46 5945430 .85 560648 .91 MWD+IFR-AK-CAZ-SC 5228 .52 81.01 181 .38 3638. 68 3517. 38 -733 .33 1880. 52 5945338 .46 560647 .69 MWD+IFR-AK-CAZ-SC 5322 .54 82.94 182 .32 3651. 80 3530. 50 -826 .37 1877. 51 5945245 .40 560645 .41 MWD+IFR-AK-CAZ-SC 5416 .46 81.95 180 .91 3664. 15 3542. 85 -919 .44 1874. 89 5945152 .33 560643 .51 MWD+IFR-AK-CAZ-SC I i 5510 .36 81.27 181 .62 3677. 85 3556. 55 -1012 .31 1872. 84 5945059 .46 560642 .19 MWD+IFR-AK-CAZ-SC ~ ~ 5604 .67 80.52 182 .56 3692. 78 3571. 48 -1105 .37 1869. 44 5944966 .38 560639 .52 MWD+IFR-AK-CAZ-SC 5698 .43 81.62 183 .36 3707. 33 3586. 03 -1197 .86 1864. 66 5944873 .86 560635 .46 MWD+IFR-AK-CAZ-SC 5792 .22 80.40 183 .22 3721. 99 3600. 69 -1290 .35 1859. 34 5944781 .35 560630 .87 MWD+IFR-AK-CAZ-SC 5886 .06 81.77 183 .66 3736. 53 3615. 23 -1382 .88 1853. 78 5944688 .78 560626 .02 MWD+IFR-AK-CAZ-SC 5962 .20 84.17 184 .51 3745. 85 3624. 55 -1458 .25 1848. 39 5944613 .38 560621 .23 MWD+IFR-AK-CAZ-SC 6056 .86 89.69 184 .00 3750. 92 3629. 62 -1552 .48 1841. 38 5944519 .11 560614 .96 MWD+IFR-AK-CAZ-SC 6155 .17 94.25 182 .35 3747. 54 3626. 24 -1650 .55 1835. 94 5944421 .00 560610 .28 MWD+IFR-AK-CAZ-SC j 6248 .65 93.98 182 .63 3740. 83 3619. 53 -1743 .70 1831. 89 5944327 .83 560606 .96 MWD+IFR-AK-CAZ-SC I, 6342 .23 91.31 179 .58 3736. 51 3615. 21 -1837 .15 1830. 09 5944234 .39 560605 .89 MWD+IFR-AK-CAZ-SC 6435 .67 89.83 178 .56 3735. 58 3614. 28 -1930 .56 1831. 61 5944140 .99 560608 .13 MWD+IFR-AK-CAZ-SC ~ 6528 .54 90.59 182 .45 3735. 24 3613. 94 -2023 .41 1830. 79 5944048 .15 560608 .04 MWD+IFR-AK-CAZ-SC 6622 .24 93.19 184 .32 3732. 15 3610. 85 -2116 .89 1825. 26 5943954 .65 560603 .24 MWD+IFR-AK-CAZ-SC 6717 .42 89.14 181 .40 3730. 21 3608. 91 -2211 .90 1820. 52 5943859 .61 560599 .24 MWD+IFR-AK-CAZ-SC 6811 .00 88.73 180 .60 3731. 95 3610. 65 -2305 .45 1818. 88 5943766 .06 560598 .34 MWD+IFR•AK-CAZ-SC 6904 .65 90.59 182 .12 3732. 51 3611. 21 -2399 .06 1816. 66 5943672 .44 560596 .84 MWD+IFR-AK-CAZ-SC 6998 .46 89.71 179 .51 3732. 26 3610. 96 -2492 .85 1815. 33 5943578 .65 560596 .24 MWD+IFR-AK-CAZ-SC 7091 .84 89.28 175 .68 3733. 09 3611. 79 -2586 .13 1819. 25 5943485 .42 560600 .89 MWD+IFR-AK-CAZ-SC 7185 .70 89.35 175 .95 3734. 21 3612. 91 -2679 .73 1826. 09 5943391 .88 560608 .47 MWD+IFR-AK-CAZ-SC 7279 .89 90.59 177 .07 3734. 26 3612. 96 -2773 .74 1831. 83 5943297 .92 560614 .93 MWD+IFR-AK-CAZ-SC 7373 .81 89.03 176 .00 3734. 57 3613. 27 -2867 .49 1837. 50 5943204 .23 560621 .34 MWD+IFR-AK-CAZ-SC 7468 .40 89.60 178 .19 3735. 70 3614. 40 -2961 .94 1842. 30 5943109 .83 560626 .87 MWD+IFR-AK-CAZ-SC - - - - ~Ialliburton Company Survey Report Compauy: ConocoPhillipsAlaska Inc. .Date: 10/16/2006 Timc: 14:49:43 Pa~,c: 3 Field: Kuparuk Riv er Unit Cu-ordinate(NE} Reference: Welh 1J-102, True North Site: Kuparuk 1J Pad ~~cilical(TVD) Reference: 1J-102PB1' 121.3 Well: 1J-102 sccri,ni (VS)'Reference: Well (O.OON,O.OOE,180.OOAzi) W'ellpath: 1J-102PB1 tiurvey Calculation Method: Minimum Curvature llb: Oracle Survey MD lncl Aziu~ TViI Sys TVD _- ' N15 t%W MapN __ MapE Tool ft deg deg ft ft ft ft ft ft 7561.99 89.22 183.00 3736.66 3615.36 -3055.49 1841.33 5943016.28 560626.63 MWD+IFR-AK-CAZ-SC 7655.58 91.27 185.66 3736.26 3614.96 -3148.80 1834.26 5942922.93 560620.29 MWD+IFR-AK-CAZ-SC 7749.84 92.81 184.64 3732.91 3611.61 -3242.62 1825.81 5942829.06 560612.57 MWD+IFR-AK-CAZ-SC ~ 7843.94 92.80 181.48 3728.30 3607.00 -3336.46 1820.79 5942735.19 560608.28 MWD+IFR-AK-CAZ-SC ! 7937.31 91.32 179.21 3724.95 3603.65 -3429.76 1820.23 5942641.90 560608.45 MWD+IFR-AK-CAZ-SC 8031.59 88.03 176.51 3725.48 3604.18 -3523.95 1823.75 5942547.75 560612.71 MWD+IFR-AK-CAZ-SC 8124.27 86.69 177.23 3729.75 3608.45 -3616.39 1828.80 5942455.36 560618.48 MWD+IFR-AK-CAZ-SC 8159.00 86.69 177.23 3731.76 3610.46 -3651.02 1830.48 5942420.74 560620.43 PROJECTED to TD ~Ialliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 10/16/2006 'l'ime: 14:57:48 Page: I Field: Kuparuk River Unit Co-ordiaate(NE) Reference: Well: 1J-102, True North Site: Kuparuk 1J Pad Ve rtical (TVD)Re ference: 1J-102P62: 121.3 Well: 1J-102 Section (V~)'Refer ence: Well (O.OON,O.O OE,155.31Azi) Wellpath: 1J-102P62 Su rvey Calculation Method: Minimum Curva ture Db: Oracle __ _ _ Field: Kuparuk River Unit _ - - North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre j Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-102 Slot Name: Well Position: +N/-S 137.61 ft Northing: 5946057.02 ft Latitude: 70 15 47.611 N j +E/-W -27.19 ft Easti ng : 558761.69 ft Longitude: 149 31 29.798 W Position Uncertainty: 0.00 ft Wellpath: 1J-102PB2 Drilled From: 1J-102P61 500292331771 Tie-on Depth: 7655.58 ft i Current Datum: 1J-102P62: Height 121.30 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angl e: 80.80 deg Vertical Section: Depth From (1'VD) +N/-S +E/-W Direction ft ft ft deg ~ 40.30 0.00 0.00 155.31 Survey Program for DeTnitive Wellpath Date: 10/16/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 121.00 820.00 1J-102PB1 gyro (12 1.00-820.00) C B-GYRO-SS Camera based gyro single shot 869.87 7655.58 1 J-102P61 (869.87- 8124.27) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7710.00 8365.02 1 J-102PB2 (7710.00-8365.02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC i Survey 'b1D Incl Azim TVD Sys 7`VD NlS E/W MapN A1apE Tool. ft deg deg ft ft ft ft ft ft 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5946057.02 558761.69 __ TIE LINE 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 CB-GYRO-SS 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS j 520.00 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS I 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+IFR-AK-CAZ-SC 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC i 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+IFR-AK-CAZ-SC 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC j 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC ~ 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+IFR-AK-CAZ-SC 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC j 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 i MWD+IFR-AK-CAZ-SC 2486.23 45.57 74.98 2142.53 2021.23 658.90 827.98 5946722.30 559584.42 MWD+IFR-AK-CAZ-SC 2581.48 43.53 80.15 2210.42 2089.12 673.33 893.17 5946737.23 559649.50 MWD+IFR-AK-CAZ-SC ~Ialliburton Company ,~ Survey Report Company: ConocoPhillipsAlaska Inc. Date: 10/16/2006 Time.. 14:57:48 Pale: 2_ Field: Kuparuk River Uni t Co-or dinate (NE) Reference. Well: 1J-102, True North Site: Kuparuk 1J Pad Vertical(TVD) Reference: ~J-102P62 : 121 .3 Wefl: 1J- 102 Sectio n (VS) Reference: Well (O.OON,O.ODE,155.31Azi) li'eElputh: 1J- 102P62 Survey Calculation Method: Minimum C urvat ure Db: Oracle Survcv >VID ]ncl - Azim TVD Sys "~~~' D N/S -_ _-_ E/W MapN Mapr~ Tool ~'~ -ft deg deg ft ft ft ft ft ft 2602 .96 43.39 80 .76 2226. 01 2104. 71 675 .78 907. 74 5946739 .80 559664 .04 MWD+IFR-AK-CAZ-SC 2692 .50 43.33 80 .12 2291. 12 2169. 82 685 .99 968. 36 5946750 .48 559724 .58 MWD+IFR-AK-CAZ-SC I I 2789 .32 41.08 80 .53 2362. 83 2241. 53 696 .92 1032. 48 5946761 .91 559788 .60 MWD+IFR-AK-CAZ-SC 2883 .45 39.91 82 .89 2434. 42 2313. 12 705 .75 1092. 95 5946771 .21 559849 .00 MWD+IFR-AK-CAZ-SC 2978 .49 42.09 87 .64 2506. 16 2384. 86 710 .84 1155. 05 5946776 .78 559911 .05 MWD+IFR-AK-CAZ-SC 3072 .35 42.28 89 .81 2575. 71 2454. 41 712 .24 1218. 06 5946778 .67 559974 .04 MWD+IFR-AK-CAZ-SC 3164 .88 43.18 96 .30 2643. 71 2522. 41 708 .87 1280. 68 5946775 .79 560036 .68 MWD+IFR-AK-CAZ-SC 3260 .78 43.19 102 .29 2713. 67 2592. 37 698 .28 1345. 39 5946765 .71 560101 .46 MWD+IFR-AK-CAZ-SC 3353 .79 43.31 108 .49 2781. 44 2660. 14 681 .38 1406. 77 5946749 .29 560162. 97 MWD+IFR-AK-CAZ-SC 3447 .64 44.63 113 .39 2849. 00 2727. 70 658 .07 1467. 58 5946726 .46 560223 .95 MWD+IFR-AK-CAZ-SC i 3541 .79 46.90 119 .91 2914. 72 2793. 42 627 .78 1527. 77 5946696 .65 560284. 36 MWD+IFR-AK-CAZ-SC 3636 .01 48.89 126 .24 2977. 92 2856. 62 589 .62 1586. 25 5946658 .95 560343 .14 MWD+IFR-AK-CAZ-SC 3729 .21 49.70 132 .74 3038. 74 2917. 44 544 .72 1640. 70 5946614 .47 560397 .94 MWD+IFR-AK-CAZ-SC 3823 .40 49.11 138 .38 3100. 06 2978. 76 493 .70 1690. 75 5946563 .85 560448 .38 MWD+IFR-AK-CAZ-SC 3916 .77 49.70 146 .22 3160. 87 3039. 57 437 .67 1734. 03 5946508 .17 560492 .09 MWD+IFR-AK-CAZ-SC ' 4010 .22 51.80 150 .91 3220. 01 3098. 71 375 .94 1771. 71 5946446 .74 560530 .25 MWD+IFR-AK-CAZ-SC 4104 .27 55.02 157 .51 3276. 11 3154. 81 307 .98 1804. 45 5946379 .04 560563. 51 MWD+IFR-AK-CAZ-SC 4198 .08 57.40 161 .80 3328. 29 3206. 99 234 .90 1831. 51 5946306 .18 560591. 13 MWD+IFR-AK-CAZ-SC 4291 .04 62.13 164 .89 3375. 10 3253. 80 157 .97 1854. 46 5946229 .45 560614 .69 MWD+IFR-AK-CAZ-SC 4384 .47 65.15 169 .96 3416. 60 3295. 30 76 .30 1872. 63 5946147 .93 560633 .49 MWD+IFR-AK-CAZ-SC 4474 .72 66.68 173 .83 3453. 44 3332. 14 -5 .25 1884. 23 5946066 .48 560645 .72 MWD+IFR-AK-CAZ-SC 4566 .87 68.47 176 .21 3488. 59 3367. 29 -90 .10 1891. 61 5945981 .70 560653 .77 MWD+IFR-AK-CAZ-SC 4664 .00 72.68 180 .95 3520. 91 3399. 61 -181 .62 1893. 83 5945890 .20 560656 .70 MWD+IFR-AK-CAZ-SC 4759 .55 77.88 181 .97 3545. 18 3423. 88 -273 .97 1891. 47 5945797 .85 560655 .06 MWD+IFR-AK-CAZ-SC 4848 .85 77.69 181 .35 3564. 07 3442. 77 -361 .21 1888. 94 5945710 .60 560653 .21 MWD+IFR-AK-CAZ-SC 4942 .22 78.44 182 .65 3583. 38 3462. 08 -452 .50 1885. 75 5945619 .29 560650 .73 MWD+IFR-AK-CAZ-SC 5040 .59 78.70 180 .15 3602. 88 3481. 58 -548 .88 1883. 40 5945522 .90 560649. 13 MWD+IFR-AK-CAZ-SC 5134 .56 78.18 181 .02 3621. 71 3500. 41 -640 .94 1882. 46 5945430 .85 560648. 91 MWD+IFR-AK-CAZ-SC 5228 .52 81.01 181 .38 3638. 68 3517. 38 -733 .33 1880. 52 5945338 .46 560647. 69 MWD+IFR-AK-CAZ-SC 5322 .54 82.94 182 .32 3651. 80 3530. 50 -826 .37 1877. 51 5945245 .40 560645. 41 MWD+IFR-AK-CAZ-SC 5416 .46 81.95 180 .91 3664. 15 3542. 85 -919 .44 1874. 89 5945152 .33 560643 .51 MWD+IFR-AK-CAZ-SC ~ 5510 .36 81.27 181 .62 3677. 85 3556. 55 -1012 .31 1872. 84 5945059 .46 560642 .19 MWD+IFR-AK-CAZ-SC ' 5604 .67 80.52 182 .56 3692. 78 3571. 48 -1105 .37 1869. 44 5944966 .38 560639 .52 MWD+IFR-AK-CAZ-SC 5698 .43 81.62 183 .36 3707. 33 3586. 03 -1197 .86 1864. 66 5944873 .86 560635 .46 MWD+IFR-AK-CAZ-SC 5792 .22 80.40 183 .22 3721. 99 3600. 69 -1290 .35 1859. 34 5944781 .35 560630 .87 MWD+IFR-AK-CAZ-SC 5886 .06 81.77 183 .66 3736. 53 3615. 23 -1382 .88 1853. 78 5944688 .78 560626 .02 MWD+IFR-AK-CAZ-SC 5962 .20 84.17 184 .51 3745. 85 3624. 55 -1458 .25 1848. 39 5944613 .38 560621. 23 MWD+IFR-AK-CAZ-SC 6056 .86 89.69 184 .00 3750. 92 3629. 62 -1552 .48 1841. 38 5944519 .11 560614. 96 MWD+IFR-AK-CAZ-SC i 6155 .17 94.25 182 .35 3747. 54 3626. 24 -1650 .55 1835. 94 5944421 .00 560610. 28 MWD+IFR-AK-CAZ-SC ~ ~I 6248 .65 93.98 182 .63 3740. 83 3619. 53 -1743 .70 1831. 89 5944327 .83 560606. 96 MWD+IFR-AK-CAZ-SC ~ 6342 .23 91.31 179 .58 3736. 51 3615. 21 -1837 .15 1830. 09 5944234 .39 560605 .89 MWD+IFR-AK-CAZ-SC i ~ 6435 .67 89.83 178 .56 3735. 58 3614. 28 -1930 .56 1831. 61 5944140 .99 560608 .13 MWD+IFR-AK-CAZ-SC i 6528 .54 90.59 182 .45 3735. 24 3613. 94 -2023 .41 1830. 79 5944048 .15 560608 .04 MWD+IFR-AK-CAZ-SC 6622 .24 93.19 184 .32 3732. 15 3610. 85 -2116 .89 1825. 26 5943954 .65 560603 .24 MWD+IFR-AK-CAZ-SC 6717 .42 89.14 181 .40 3730. 21 3608. 91 -2211 .90 1820. 52 5943859 .61 560599 .24 MWD+IFR-AK-CAZ-SC 6811 .00 88.73 180 .60 3731. 95 3610. 65 -2305 .45 1818. 88 5943766 .06 560598. 34 MWD+IFR-AK-CAZ-SC 6904 .65 90.59 182 .12 3732. 51 3611. 21 -2399 .06 1816. 66 5943672 .44 560596. 84 MWD+IFR-AK-CAZ-SC 6998 .46 89.71 179 .51 3732. 26 3610. 96 -2492 .85 1815. 33 5943578 .65 560596. 24 MWD+IFR-AK-CAZ-SC 7091 .84 89.28 175 .68 3733. 09 3611. 79 -2586 .13 1819. 25 5943485 .42 560600. 89 MWD+IFR-AK-CAZ-SC 7185 .70 89.35 175 .95 3734. 21 3612. 91 -2679 .73 1826. 09 5943391 .88 560608. 47 MWD+IFR-AK-CAZ-SC ~ 7279 .89 90.59 177 .07 3734. 26 3612. 96 -2773 .74 1831. 83 5943297 .92 560614. 93 MWD+IFR-AK-CAZ-SC 7373 .81 89.03 176 .00 3734. 57 3613. 27 -2867 .49 1837. 50 5943204 .23 560621 .34 MWD+IFR-AK-CAZ-SC ~ , -- ~Ialliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 10/16/2006 7 ime: 14:57:48 Pale: 3 Field: Kuparuk Riv er Unit Co-ordinate(NE) Reference: Well: 1J-102, True North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: 1 J-102PB2: 121.3 Well: 1J -102 ' Sectio n (VS) Reference:- Well (O.OON,O.O OE,155 31Azi) Wellpath: 1J -102P62 Survey Calculati on Method: Minimum Curvature llb: Oracle Sure ev _ ', b1D Intl Azim PVD Sys TVD N/S E/~V blap\ A1apE Tool ~, ft '- deg deg ft ft ft ft ' ft ft 7468.40 89.60 178.19 3735.70 3614.40 -2961.94 1842.30 5943109.83 560626.87 MWD+IFR-AK-CAZ-SC ~ 7561.99 89.22 183.00 3736.66 3615.36 -3055.49 1841.33 5943016.28 560626.63 MWD+IFR-AK-CAZ-SC 7655.58 91.27 185.66 3736.26 3614.96 -3148.80 1834.26 5942922.93 560620.29 MWD+IFR-AK-CAZ-SC ~ 7710.00 92.16 185.07 3734.64 3613.34 -3202.96 1829.18 5942868.74 560615.63 MWD+IFR-AK-CAZ-SC 7750.81 91.44 182.47 3733.35 3612.05 -3243.66 1826.49 5942828.03 560613.26 MWD+IFR-AK-CAZ-SC 7844.48 89.77 176.43 3732.36 3611.06 -3337.27 1827.39 5942734.43 560614.89 MWD+IFR-AK-CAZ-SC 7938.20 87.80 175.00 3734.35 3613.05 -3430.70 1834.39 5942641.07 560622.62 MWD+IFR-AK-CAZ-SC 8032.27 87.24 179.29 3738.42 3617.12 -3524.54 1839.07 5942547.27 560628.03 MWD+IFR-AK-CAZ-SC 8125.63 89.30 182.87 3741.24 3619.94 -3617.83 1837.31 5942453.99 560627.00 MWD+IFR-AK-CAZ-SC 8218.11 89.91 189.84 3741.88 3620.58 -3709.68 1827.08 5942362.07 560617.49 MWD+IFR-AK-CAZ-SC 8312.03 89.90 192.65 3742.04 3620.74 -3801.79 1808.77 5942269.83 560599.90 MWD+IFR-AK-CAZ-SC i 8365.02 91.96 194.72 3741.18 3619.88 -3853.26 1796.24 5942218.27 560587.77 MWD+IFR-AK-CAZ-SC 8401.00 91.96 194.72 3739.95 3618.65 -3888.04 1787.10 5942183.42 560578.90 PROJECTED to TD ~Ialliburton Company Survey Report Company: ConocoPhillipsAlaskainc. Uate: 10/1612D06 l~imr. 15.14:50 Pagr: 1 Field: Kuparuk River Unit Cu -ordinate(NE) Refrrcncr. Well: 1J-102, Tr ue North Site: .Kuparuk 1J Pad ~"c rCical(TVD)Re ferc~icc: 1J-902PB3: 121 .3 ~ticll: 1J-102 ticction (VS) Refe rence: Well (090N,O.O OE160.71Azi) 1~cllparlr 1J-102PB3 Su rvey Calculatio n ~dethod: Minimum Curva ture Db: Oracle __ Field: Kuparuk River Unit __ __ North Slope Alaska United States Map System:US State Plane Coordin Geo Datum: NAD27 (Clarke 1866) ate System 1927 Map Zone: Coordinate Sy Alaska, Zone 4 stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-102 Slot Name: Well Position: +N/-S 137.61 ft Northing: 5946057.02 ft Latitude: 70 15 47.611 N +E/-W -27.19 ft Easting : 558761.69 ft Longitude: 149 31 29.798 W Position Uncertainty: 0.00 ft Wellpath: 1J-102PB3 Drilled From: 1J-102P61 500292331772 Tie-on Depth: 7561.99 ft Current Datum: 1 J-102PB3: Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From ('TVD) +N/-S +E/-W Direcfion ft ft ft deg 40.30 0.00 0.00 160.71 Survey Program for Definitive Wellpath Date: 10/16/2006 Validated: No Version: 1 ~ Actual From To Survey Toolcode Tool Name ft ft 121.00 820.00 1J-102P61 gyro (121.00-820.00) CB-GYRO-SS Camera based gyro single shot 869.87 7561.99 1J-102P61 (869.87-8124.27) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 7600.00 9812.41 1J-102PB3(7600.00-9812.41) MWD+IFR-AK-CAZ-SC MWD+IFR AKCAZSC C Survey - _ _ __ - __ - -- - ', iV1D lncl Azim TVll Sys TVD N/S E,~~`,~ blapN iV1apE -fool ft deg deg ft ft ft ft ft ft - ~~ 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5946057.02 558761.69 ____ TIE LINE I 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 CB-GYRO-SS ~ ' 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS 520.00 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+IFR-AK-CAZ-SC 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+IFR-AK-CAZ-SC i 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC i 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+IFR-AK-CAZ-SC 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 MWD+IFR-AK-CAZ-SC '~ 2486.23 45.57 74.98 2142.53 2021.23 658.90 827.98 5946722.30 559584.42 MWD+IFR-AK-CAZ-SC 2581.48 43.53 80.15 2210.42 2089.12 673.33 893.17 5946737.23 559649.50 MWD+IFR-AK-CAZ-SC ~Ialliburton Company Survey Report Company: ConocoPhillipsAlaska Inc. Firld: Kuparuk Riv er Unit 1ilc: Kuparuk 1J Pad WeII: 1J -102 W ellpath: 1 J -102PB3 Sure c~~ ___ __ MD lucl Azirn 'C ft deg deg 2602.96 43.39 80.76 2 2692.50 43.33 80.12 2 2789.32 41.08 80.53 2 2883.45 39.91 82.89 2 2978.49 42.09 87.64 2 3072.35 42.28 89.81 2 3164.88 43.18 96.30 2 3260.78 43.19 102.29 2 3353.79 43.31 108.49 2 3447.64 44.63 113.39 2 3541.79 46.90 119.91 2 3636.01 48.89 126.24 2 3729.21 49.70 132.74 3 3823.40 49.11 138.38 3 3916.77 49.70 146.22 3 4010.22 51.80 150.91 3 4104.27 55.02 157.51 3 4198.08 57.40 161.80 3 4291.04 62.13 164.89 3 4384.47 65.15 169.96 4474.72 66.68 173.83 3 4566.87 68.47 176.21 3 4664.00 72.68 180.95 3 4759.55 77.88 181.97 3 4848.85 77.69 181.35 3 4942.22 78.44 182.65 3 5040.59 78.70 180.15 3 5134.56 78.18 181.02 3 5228.52 81.01 181.38 3 5322.54 82.94 182.32 3 5416.46 81.95 180.91 3 5510.36 81.27 181.62 3 5604.67 80.52 182.56 3 5698.43 81.62 183.36 3 5792.22 80.40 183.22 3 5886.06 81.77 183.66 3 5962.20 84.17 184.51 3 Date: 10/16/2006 "1'iroe: 15:14:50 1'rr~e: 2 Co-ordinate(NE) Reference: WeII: 1J-102, True North .Vertical (fVDj Reference: 1 J-102PB3: 121.3 Section (VS}Reference: WeII (O.OON,O.OOE,160.71Azi) Survey' Calculation Method: Minimum Curvature Db: Oracle VD Sys TVD N/S ft ft ft 226.01 2104.71 675.78 291.12 2169.82 685.99 362.83 2241.53 696.92 434.42 2313.12 705.75 506.16 2384.86 710.84 575.71 2454.41 712.24 643.71 2522.41 708.87 713.67 2592.37 698.28 781.44 2660.14 681.38 849.00 2727.70 658.07 914.72 2793.42 627.78 977.92 2856.62 589.62 038.74 2917.44 544.72 100.06 2978.76 493.70 160.87 3039.57 437.67 220.01 3098.71 375.94 276.11 3154.81 307.98 328.29 3206.99 234.90 375.10 3253.80 157.97 3416.60 3295.30 76.30 453.44 3332.14 -5.25 488.59 3367.29 -90.10 520.91 3399.61 -181.62 545.18 3423.88 -273.97 564.07 3442.77 -361.21 583.38 3462.08 -452.50 602.88 3481.58 -548.88 621.71 3500.41 -640.94 638.68 3517.38 -733.33 651.80 3530.50 -826.37 664.15 3542.85 -919.44 677.85 3556.55 -1012.31 692.78 3571.48 -1105.37 707.33 3586.03 -1197.86 721.99 3600.69 -1290.35 736.53 3615.23 -1382.88 745.85 3624.55 -1458.25 E/W MapN ft ft 907.74 5946739.80 968:36 5946750.48 1032.48 5946761.91 1092.95 5946771.21 1155.05 5946776.78 1218.06 5946778.67 1280.68 5946775.79 1345.39 5946765.71 1406.77 5946749.29 1467.58 5946726.46 1527.77 5946696.65 1586.25 5946658.95 1640.70 5946614.47 1690.75 5946563.85 1734.03 5946508.17 1771.71 5946446.74 1804.45 5946379.04 1831.51 5946306.18 1854.46 5946229.45 1872.63 5946147.93 1884.23 5946066.48 1891.61 5945981.70 1893.83 5945890.20 1891.47 5945797.85 1888.94 5945710.60 1885.75 5945619.29 1883.40 5945522.90 1882.46 5945430.85 1880.52 5945338.46 1877.51 5945245.40 1874.89 5945152.33 1872.84 5945059.46 1869.44 5944966.38 1864.66 5944873.86 1859.34 5944781.35 1853.78 5944688.78 1848.39 5944613.38 MapE Tool ft 559664.04 __ _ _. MWD+IFR-AK-CAZ-SC 559724.58 MWD+IFR-AK-CAZ-SC 559788.60 MWD+IFR-AK-CAZ-SC 559849.00 MWD+IFR-AK-CAZ-SC 559911.05 MWD+IFR-AK-CAZ-SC 559974.04 MWD+IFR-AK-CAZ-SC 560036.68 MWD+IFR-AK-CAZ-SC 560101.46 MWD+IFR-AK-CAZ-SC 560162.97 MWD+IFR-AK-CAZ-SC 560223.95 MWD+IFR-AK-CAZ-SC 560284.36 MWD+IFR-AK-CAZ-SC 560343.14 MWD+IFR-AK-CAZ-SC 560397.94 MWD+IFR-AK-CAZ-SC 560448.38 MWD+IFR-AK-CAZ-SC 560492.09 MWD+IFR-AK-CAZ-SC 560530.25 MWD+IFR-AK-CAZ-SC 560563.51 MWD+IFR-AK-CAZ-SC 560591.13 MWD+IFR-AK-CAZ-SC 560614.69 MWD+IFR-AK-CAZ-SC 560633.49 MWD+IFR-AK-CAZ-SC 560645.72 MWD+IFR-AK-CAZ-SC 560653.77 MWD+IFR-AK-CAZ-SC 560656.70 MWD+IFR-AK-CAZ-SC 560655.06 MWD+IFR-AK-CAZ-SC 560653.21 MWD+IFR-AK-CAZ-SC 560650.73 MWD+IFR-AK-CAZ-SC 560649.13 MWD+IFR-AK-CAZ-SC 560648.91 MWD+IFR-AK-CAZ-SC 560647.69 MWD+IFR-AK-CAZ-SC 560645.41 MWD+IFR-AK-CAZ-SC 560643.51 MWD+IFR-AK-CAZ-SC 560642.19 MWD+IFR-AK-CAZ-SC 560639.52 MWD+IFR-AK-CAZ-SC 560635.46 MWD+IFR-AK-CAZ-SC 560630.87 MWD+IFR-AK-CAZ-SC 560626.02 MWD+IFR-AK-CAZ-SC 560621.23 MWD+IFR-AK-CAZ-SC 560614.96 MWD+IFR-AK-CAZ-SC 560610.28 MWD+IFR-AK-CAZ-SC 560606.96 MWD+IFR-AK-CAZ-SC 560605.89 MWD+IFR-AK-CAZ-SC 560608.13 MWD+IFR-AK-CAZ-SC 560608.04 MWD+IFR-AK-CAZ-SC 560603.24 MWD+IFR-AK-CAZ-SC 560599.24 MWD+IFR-AK-CAZ-SC 560598.34 MWD+IFR-AK-CAZ-SC 560596.84 MWD+IFR-AK-CAZ-SC 560596.24 MWD+IFR-AK-CAZ-SC 560600.89 MWD+IFR-AK-CAZ-SC 560608.47 MWD+IFR-AK-CAZ-SC 560614.93 MWD+IFR-AK-CAZ-SC 560621.34 MWD+IFR-AK-CAZ-SC 6056.86 89.69 184 .00 3750 .92 3629. 62 -1552.48 1841. 38 5944519.11 6155.17 94. 25 182 .35 3747 .54 3626. 24 -1650.55 1835. 94 5944421.00 6248.65 93. 98 182 .63 3740 .83 3619. 53 -1743.70 1831. 89 5944327.83 6342.23 91. 31 179 .58 3736 .51 3615. 21 -1837.15 1830. 09 5944234.39 6435.67 89. 83 178 .56 3735 .58 3614. 28 -1930.56 1831. 61 5944140.99 6528.54 90. 59 182 .45 3735 .24 3613. 94 -2023.41 1830. 79 5944048.15 6622.24 93. 19 184 .32 3732 .15 3610. 85 -2116.89 1825. 26 5943954.65 6717.42 89. 14 181 .40 3730 .21 3608. 91 -2211.90 1820. 52 5943859.61 6811.00 88. 73 180 .60 3731 .95 3610. 65 -2305.45 1818. 88 5943766.06 6904.65 90. 59 182 .12 3732 .51 3611. 21 -2399.06 1816. 66 5943672.44 6998.46 89. 71 179 .51 3732 .26 3610. 96 -2492.85 1815. 33 5943578.65 7091.84 89. 28 175 .68 3733 .09 3611. 79 -2586.13 1819. 25 5943485.42 7185.70 89. 35 175 .95 3734 .21 3612. 91 -2679.73 1826. 09 5943391.88 7279.89 90. 59 177 .07 3734 .26 3612. 96 -2773.74 1831. 83 5943297.92 7373.81 89. 03 176 .00 3734 .57 3613. 27 -2867.49 1837. 50 5943204.23 ~Ialliburton Company Survey Report Company: ConocoPhiltipsAlaska Inc. Date: '10/16/2006 7~imc: 15:14'50 Page: 3 Field: KuparukRiv er Unit Co-ordinate(NE) Reference. WeIL 1J-102, True North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: 13-102PB3: 121.3 Well:- iJ -102 sectio n (VS) Reference: Well (0-OON,QO OE,160.71Azi) We)Ipath: 1J -102P83 survey Calculation Method: Minirrnum Curvature llb: Oracle tiur~ev MD Incl Arim TVD SgsTVD 11'/S E/~V ~1apN M;~pl: Tuul ft deg deg ft ft ft ft ft ft 7468.40 89.60 178.19 3735.70 ___ 3614.40 -2961.94 1842.30 5943109.83 560626.87 MWD+IFR-AK-CAZ-SC 7561.99 89.22 183.00 3736.66 3615.36 -3055.49 1841.33 5943016.28 560626.63 MWD+IFR-AK-CAZ-SC ~ 7600.00 90.05 184.08 3736.91 3615.61 -3093.43 1838.98 5942978.33 560624.58 MWD+IFR-AK-CAZ-SC 7654.14 88.40 184.13 3737.64 3616.34 -3147.43 1835.10 5942924.31 560621.12 MWD+IFR-AK-CAZ-SC 7751.11 91.65 183.93 3737.60 3616.30 -3244.14 1828.29 5942827.56 560615.06 MWD+IFR-AK-CAZ-SC i 7844.06 90.95 182.95 3735.49 3614.19 -3336.90 1822.71 5942734.77 560610.21 MWD+IFR-AK-CAZ-SC 7937.60 88.53 185.01 3735.91 3614.61 -3430.20 1816.22 .5942641.43 560604.45 MWD+IFR-AK-CAZ-SC 8031.15 91.15 182.05 3736.17 3614.87 -3523.55 1810.46 5942548.04 560599.42 MWD+IFR-AK-CAZ-SC 8123.52 89.96 180.25 3735.28 3613.98 -3615.90 1808.61 5942455.70 560598.29 MWD+IFR-AK-CAZ-SC 8217.41 90.40 178.82 3734.98 3613.68 -3709.78 1809.37 5942361.83 560599.78 MWD+IFR-AK-CAZ-SC 8312.47 91.02 178.47 3733.81 3612.51 -3804.81 1811.62 5942266.83 560602.77 MWD+IFR-AK-CAZ-SC 8405.93 89.28 175.82 3733.56 3612.26 -3898.14 1816.28 5942173.55 560608.15 MWD+IFR-AK-CAZ-SC 8500.07 90.40 174.02 3733.82 3612.52 -3991.90 1824.61 5942079.86 560617.22 MWD+IFR-AK-CAZ-SC 8590.58 89.22 174.88 3734.12 3612.82 -4081.98 1833.36 5941989.86 560626.68 MWD+IFR-AK-CAZ-SC 8687.42 87.18 178.04 3737.17 3615.87 -4178.57 1839.34 5941893.33 560633.41 MWD+IFR-AK-CAZ-SC 8781.20 90.54 178.71 3739.03 3617.73 -4272.28 1842.00 5941799.65 560636.79 MWD+IFR-AK-CAZ-SC 8874.70 90.46 178.86 3738.22 3616.92 -4365.76 1843.98 5941706.20 560639.51 MWD+IFR-AK-CAZ-SC 8968.59 91.51 179.54 3736.60 3615.30 -4459.62 1845.29 5941612.36 560641.55 MWD+IFR-AK-CAZ-SC 9062.10 88.03 179.64 3736.98 3615.68 -4553.12 1845.96 5941518.88 560642.95 MWD+IFR-AK-CAZ-SC 9155.78 89.23 179.02 3739.22 3617.92 -4646.76 1847.06 5941425.26 560644.77 MWD+IFR-AK-CAZ-SC 9249.70 89.91 180.97 3739.92 3618.62 -4740.67 1847.06 5941331.36 560645.51 MWD+IFR-AK-CAZ-SC 9342.65 91.77 180.82 3738.56 3617.26 -4833.60 1845.61 5941238.44 560644.79 MWD+IFR-AK-CAZ-SC 9436.07 92.76 181.02 3734.87 3613.57 -4926.93 1844.11 5941145.10 560644.02 MWD+IFR-AK-CAZ-SC 9531.12 88.09 181.66 3734.16 3612.86 -5021.93 1841.89 5941050.10 560642.54 MWD+IFR-AK-CAZ-SC 9623.46 88.36 175.93 3737.03 3615.73 -5114.16 1843.83 5940957.89 560645.20 MWD+IFR-AK-CAZ-SC 9718.82 85.03 173.37 3742.52 3621.22 -5208.93 1852.70 5940863.21 560654.81 MWD+IFR-AK-CAZ-SC 9812.41 87.76 173.61 3748.41 3627.11 -5301.72 1863.29 5940770.51 560666.12 MWD+IFR-AK-CAZ-SC 9846.00 87.76 173.61 3749.72 3628.42 -5335.08 1867.03 5940737.19 560670.11 PROJECTED to TD ConocoPhiiii ~ Time Lo Summa b~~,r~.~~,~ ~~~~~' a,~t~~~ 9 rY _Time Logs -- --- -- - - Date From To Dur S. De `th E. De th Phase Code Subcode T COM 08/15/2006 06:00 10:00 4.00 MIRU MOVE DMOB _ P _ Rig Released form 1J-109 @ 0600 HRS. Prepare Rig Floor for Skid. Rig down Handi-Berms on Pit Module, Clean out Cellar Box & Pollution Pan. Move Rock Washer. 10:00 11:30 1.50 MIRU MOVE SFTY P Held "Fall Arrest" Training at Deyon 141. 11:30 12:15 0.75 MIRU MOVE DMOB P PJSM wit crew. Discuss Safety Issues and procedure for moving Rig and Modules. Discuss new hands in new ositions. 12:15 13:00 0.75 MIRU MOVE DMOB P Turn tires on rig, and install drag Links on front & rear of it module. 13:00 14:15 1.25 MIRU MOVE SFTY P Held "Fall Arrest" Training at Doyon 141 with rew #2. 14:15 14:45 0.50 MIRU MOVE DMOB P Move Pit Complex out of the way and down the ad. 14:45 15:00 0.25 MIRU MOVE DMOB P PJSM with crew. Discuss Safety issue s and procedure for skidding rig floor and derrick. 15:00 16:45 1.75 MIRU MOVE DMOB P Skid rig floor and Derrick. 16:45 17:00 0.25 MIRU MOVE SFTY P PJSM with crew and Crane operator. Discuss safety issues and procedurte for removing windwall section from roof of ri floor. 17:00 18:00 1.00 MIRU MOVE DMOB P Rig up & remove windwall section from roof of rig, with crane. No issues. Crew Chan e 18:00 19:00 1.00 MIRU MOVE DMOB P Prepare cellar for rig move. Lift Stompers, open windwall doors, and chain off same. Prepare Sub Complex for movin . 19:00 20:30 1.50 MIRU MOVE MOB P Move Sub Module off of 1J-109, onto ad area out of the wa . 20:30 23:00 2.50 MIRU MOVE MOB P Remove and stack all matting boards used under rig. Remove all pit liner. Clean location area, and set down Pit Liner on 1J-102. 23:00 00:00 1.00 MIRU MOVE MOB P Continue laying down pit liner on 1J-102 location. Install rig mats as tanned for ri move. 08/16/2006 00:00 03:00 3.00 MIRU MOVE MOB P Continue to set matting boards on location in re aration for ri move. 03:00 06:00 3.00 MIRU MOVE MOB P Move sub base over well to spot and center u .Crew Chan e - __ e®~ _.._ _... eee ®~ _ __ __ . e~__s ~_ ~ m_ ~. A e ~ me. m ..._~n __ ~~ ..ew ~_ . ,_~ ~.___ ~ ~e ~__ _ _ ~~.a_~_ ~_~..~. _.~_.,~ ~ m.-a .~ ~ ~ _, n® ~ ~.._~~~,,~ ~ _ _i Time L~ __ ___ __ _ Date From To Dur S. i E. De th Phase Code Subcode T 08/16/2006 06:00 12:00 6.00 MIRU MOVE MOB P ~ontinue to move & spot pit complex. Level rig and pit complex. Lower stompers in cellar. Rig released to Summer Maintenance schedule @ 1200 HRS. 12:00 00:00 12.00 MIRU RIGMN RGRP P Summer Maintenance. Details in Non Well Activit re ort. 08/24/2006 18:00 00:00 6.00 MIRU WELCT NUND P Rig accepted @ 1800 HRS as per Doyon 15 Rig acceptance checklist. Nipple up diverter system &diverter lines, and check lock downs as per Vetco Rep. Install signs on location for rig on diverter. Check & trim all herculite. Pull hand tools, tongs, elevators and slips to rig floor. Load mud pits with 1 load of spud mud from plant. Load & strap 5" DP &HWDP into shed. Load BHA into pipe shed. Inspect & adjust brakes on draw works. 08/25/2006 00:00 02:30 2.50 MIRU DRILL RURD P Install signs on location for rig on diverter. Check & trim all herculite. Pull hand tools, tongs, elevators and slips to rig floor. Load mud pits with 1 load of spud mud from plant. Strap 5" DP & HWDP in shed. Load BHA into pipe shed. Inspect & adjust brakes on draw works. Install mouse hole in rotary table for ickin u DP. 02:30 03:00 0.50 MIRU DRILL SFTY P Held PJSM with entire crew and Varco representative. Discuss safety issues and procedure for picking up 5" DP and racking back same. Discuus training on new ST-80 Iron roughneck while PU DP. 03:00 06:00 3.00 MIRU DRILL PULD P Pickup 63 joints (21 stands) of 5" drill pipe from shed. Rack back in derrick. NOTE: Varco rep on rig floor training hands on operation of new ST-80 iron roughneck. Pick up 20 joints of 5" HWDP with 8" Drilling jars, and rack back in derrick. Crew Change. Note: Rig crews attending SIMS training @ KOC. 06:00 06:15 0.25 MIRU DRILL RURD P Calibrate Block Height for MWD. 06:15 07:00 0.75 MIRU DRILL PULD P Continue to pickup 5" HWDP and rack back stands in derrick. Total of 7 Stands. 07:00 08:45 1.75 MIRU DRILL RURD P Pull mouse hole from rotary table. Pick up 8" Dailey drilling jar, and make up to 5" HWDP double, rack in derrick. Ins ect saver sub. e -- _e~ . ®a m ~~ ~ ~ ~ _ m ~ m ~®~ ~ ~ ~ ~~~ .. ~_ ~m~ ~ „a M - t ~4 Time Logs ---- - _ - _ _ _ _ Date From To Dur S E. De th Phase Code Subcode T 08/25/2006 08:45 09:15 0.50 MIRU RIGMN RGRP P Clean & clear rig floor area. Rig up to change out saver sub on Top Drive. Held PJSM -discuss safety issues and procedure for changing out saver sub. Discuss hazards and record on HR card. 09:15 11:30 2.25 MIRU RIGMN RGRP P Change out saver sub on Top Drive. 11:30 12:00 0.50 MIRU DRILL OTHR P Pick up 1 stand of DP from derrick. RIH tag bottom @ 106' RKB, Indicating 14' of cement to drill. 12:00 12:30 0.50 MIRU WELCT BOPE P Function test 21 1/4" Diverter system. Check all lines & valves. Hydril closed in 33 seconds, Knife valve in 3 seconds. Accumulator system pressure = 2900 PSI. 5 bottle nitogen pressure avg = 2400 PSI. All gas alarms tested. Witness of test waived b Chuck Sheave with AOGCC. 12:30 13:15 0.75 MIRU WELCT BOPS P Perform Accumulator draw down test. Pressure from 2900 PSI, to 1600 PSI when closed. 33 seconds for 200 PSI increase with full Accumulator pressure back @ 2 minutes, 12 seconds. 13:15 14:00 0.75 MIRU WELCT BOPE P Flood all lines & diverter system. Perform surface equipment test on all equipment & lines to 2500 PSI. Low ressure test 500 PSI. 14:00 14:45 0.75 MIRU DRILL RURD P Held PJSM. Discuss safety issues and procedure for rigging up Halliburton Gyro survey unit. Spot & Rig up unit with sheaves to ri floor. 14:45 16:15 1.50 SURFA DRILL PULD P Make up BHA #1.13 1/2" drilling assembly with 13 1/2" Hughes MX-1 PDC bit with 1 x 13, and 3 x 20 jets for a TFA of 1.050 Sq in" (1.70') SperryDrill Lobe 4/5 - 5.3 stage 28.85' & HWDP to s ud. 16:15 16:30 0.25 106 120 SURFA DRILL DRLG P RIH with drilling assembly. Tag and wash from 106' - 120' MD. Observe cement returns. 16:30 17:30 1.00 120 220 SURFA DRILL DDRL P Spud & directional drill 13 1/2" surface hole from 120' - 220' MD(100'). TVD = 220'. UP WT = 92K, SO WT = 80K, ROT WT = 80K. 50 RPM's. Pumps @ 450 GPM's - 700 PSI. 750 PSI on bottom. Max gas = 18.1 units. Bit Hrs _ .77, AST = .77 HRS. Total Jar Hrs = 74.45. Mud wt = 9.0 PPG, Visc = 320, YP = 63, Gels 39/59/67 17:30 18:00 0.50 220 30 SURFA DRILL TRIP P POOH with drilling assembly from 220' to 30' for make up of remaining BHA. Crew than e. 18:00 19:00 1.00 30 122 SURFA DRILL PULD P Pick up 3 Non Mag Flex drill collars. 92.03' from i r shed. ~~_._ _ ~.e e.. a ..®~ ~_ _ ~~ e®.. ®~... .ma....e. -__.~~.~.~m ..~~.. ee_~-_ ~~ ~~a~ °~ ._ ~ ~_ _._~~.........~ ~..~- ~~~~__.. me~~_~~ ~.~.._._ __~_.._®.~.. _...~_mem__ M~a...~1 - - - - - -- -- Time Lois _ _ ~ _ Date Fram To Dur S. I_ i E. Depth Phase Code Subcode T f~A 08/25/2006 19:00 00:00 5.00 220 570 ___ SURFA T DRILL DDRL P __,_ _ Continue driectional drill 13 1/2" surface hole from 220' - 570' MD(350'). TVD = 563'. UP WT = 108K, SO WT = 105K, ROT WT = 105K. WOB = 10-30K. 50 RPM's. Pumps @ 525 GPM's - 1250 PSI. 1300 PSI on bottom. Max gas = 0 units:. Bit Hrs = 3.27, ADT = 2.50 Hrs, AST = 2.10 HRS. ART = .40 Total Jar Hrs = 76.95. Mud wt = 9.0 PPG, Visc = 320, YP = 63, Gels @ 39/59/67. Obtain Gyro surve s 121' and 220'. 08/26/2006 00:00 04:00 4.00 570 905 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 570' - 905' MD(335'). TVD = 874'. UP WT = 114K, SO WT = 111 K, ROT WT = 110K. WOB = 10-20K. 90 RPM's. Pumps @ 700 GPM's - 1850 PSI. 1950 PSI on bottom. Max gas = 0 units. Bit Hrs = 5.52, ADT = 2.25 Hrs, AST = 2.00 HRS. ART = .25 Total Jar Hrs = 79.20. Mud wt = 9.4 PPG, Visc = 280, YP = 60, Gels 39/59/67. Crew Chan e 04:00 04:45 0.75 905 905 SURFA DRILL SRVY P Run Gyro surveys at depths of 220', 320', 420', 520', 620', 720', and 820'. WLOH & rig down Halliburton gyro unit. 04:45 06:00 1.25 905 1,041 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 905' - 1041 MD(136'). TVD = 1008'. UP WT = 122K, SO WT = 115K, ROT WT = 120K. WOB = 20-25K. 90 RPM's. Pumps @ 600 GPM's - 1700 PSI. 1800 PSI on bottom. Max gas = 10 urrits. $it Hrs = 6.44, ADT = 3.17 Hrs, AST = 2.10 HRS. ART = 1.07 Total Jar Hrs = 80.12. Mud wt = 9.3 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 964.72 MD, TVD - 936', INC = 24.49 De , AZ - 38.35 De .Crew Chan e 06:00 12:00 6.00 1,041 1,634 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 1041' - 1634' MD(593'). TVD = 1529'. UP WT = 142K, SO WT = 121 K, ROT WT = 130K. WOB = 20-30K. 90 RPM's. Pumps @ 650 GPM's - 1950 PSI. 2280 PSI on bottom. Max gas = 42 units. Bit Hrs = 10.06, ADT = 3.62 Hrs, AST = 2.24 HRS. ART = 1.38 Total Jar Hrs = 83.74. Mud wt = 9.3 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 1631.24 MD, TVD - 1525.25', INC = 32.51 Deg, AZ - 50.90 De . ~..m ~ ~~ _ _ ,.wa. d ~_ ~ ®w ~._~___. ®~ . '~ c ~ ~ ~ ', ~s_~_m ___ ~ _ ~ __~ W...__....... _.~_..~__ __., .~ ~. Time Logs _ _ _ __ Date From To_ Dur S'.i E. De th Phase Code Subcode T 08/26/2006 12:00 18:00 6.00 1,634 2,262 SURFA _ DRILL DDRL P _ _ Continue driectional drill 13 1/2" surface hole from 1634' - 2262' MD(628'). TVD = 1986'. UP WT = 146K, SO WT = 125K, ROT WT = 135K. WOB = 20-30K. 90 RPM's. Pumps @ 650 GPM's - 2000 PSI. 2350 PSI on bottom. Maxgas = 42 units. Bit Hrs = 12.72, ADT = 2.66 Hrs, AST = 1.40 HRS. ART = 1.26 Total Jar Hrs = 86.40. Mud wt = 9.4 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 2201.01 MD, ND - 1945.75', INC = 47.60 Deg, AZ - 61.41 De .Crew Chan e 18:00 22:00 4.00 2,262 2,652 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 2262' - 2652' MD(390'). TVD = 2259'. UP WT = 160K, SO WT = 122K, ROT WT = 135K. WOB = 20-25K. 90 RPM's. Pumps @ 700 GPM's - 2350 PSI. 2500 PSI on bottom. IVC~ix gas = X40 units. Bit Hrs = 15.10, ADT = 2.38 Hrs, AST = 1.22 HRS. ART = 1.16 Total Jar Hrs = 88.78. Mud wt = 9.4 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 2602.96 MD, TVD - 2226.01', INC = 43.39 Deg, AZ - 80.76 Deg. Obtain last survey on bottom. 22:00 00:00 2.00 2,652 1,965 SURFA DRILL REAM P BROOH from 2652' -1965' (687'). pumps @ 700 GPMs - 2300 PSI. 90 RPM's with 3-5K torque. Pull slow for 4 stands at 10 ft/ minute allowing for good bottoms up. Then increase pulling speed to 35 - 40 ft/minute. Decrease pump rates to 600 GPMs- 2000 PSI @ 2000'. Observe good hole conditions. 08/27/2006 00:00 02:00 2.00 1,965 791 SURFA DRILL REAM P Continue BROOH from 1965' - 791' (1174'). Pumps @ 500 GPMs - 1650 PSI. 90 RPM's with 3-5K torque. Pulling speed @ 45 - 50 ft/minute. Decrease pump rates to 500 GPMs- 1350 PSI @ 1300'. Observe good hole conditions. 02:00 02:15 0.25 791 791 SURFA DRILL PULD P Clean, breakout & lay down 13 1/Z" Ghost reamer. 02:15 04:45 2.50 791 66 SURFA DRILL TRIP P Continue POOH on elevators from 791' - 66' racking back 5" HWDP & drilling jars (655'), and laying down 3 - 8" Non Mag Flex drill collars (93.03'). Breakout & lay down 8" Non Mag UBHO sub (3.38'), and 8" Non mag Flaot Sub (2.41'). Observing good hole conditions with ro er hole fill. .~~.... .- A®~~ _._~ ~~ ~®®...~ _vem - A-® ~_ ..~e.® __n._ ,__..__w~~~ w_.... ~. ~~ I a tae s f ~~` ;s~._.~ __..__ _.._ ~ . ®e~ __._...._ __ _- ....._e~ __~ ~ _._. _ ._........~ _.._._.M__..... _. ~ . _ ~ ~._._~ ~ W..._..._.._. ~_ ~ ~ .W_i Time Logs_ Date From To _ _Dur S. E. Depth Phase Code Subcode T _ 08/27/2006 04:45 05:15 0.50 66 0 SURFA DRILL PULD P Continue POOH break out & lay down remaining BHA. Lay down 8" MPT w/ DIR (24.97'), 8" Non Mag pressure drop sub (2.03'), 8" Integral Blade Stabilizer (6.99'), *" SperyDrill Lobe 4/5 - 5.3 stg Mud motor (28.85'), and 13 1/2" Hughes MX-1 Bit. Inspect & gauge bit to 2/1/BT/I/E/1/16/ER/TD 05:15 05:45 0.50 0 0 SURFA DRILL PULD P Clean & clear Floor area. Lay down tools. 05:45 06:00 0.25 0 0 SURFA CASIN( RURD P Rig up to run 10 3/4 casing. Rig up to make dummy run with casing hanger & landin 'oint. Crew Chan e 06:00 08:00 2.00 0 0 SURFA CASIN( RURD P Continue rig up to run 10 3/4" casing strin .. 08:00 08:15 0.25 0 0 SURFA CASIN( SFTY P Held PJSM with crew &GBR casing service. Discuss Safety issues and rocedure for runnin 10 3/4" Casin . 08:15 12:00 3.75 0 1,250 SURFA CASIN( RNCS P Make up 10 3/4" shoe joint with Weatherford Model 303 Sure Seal Float shoe (1.75'), and 2 joints 10 3/4 45.5# L80 casing (79.88') Weather Model 402 Sure Seal Float Collar (1.42'). Check floats -Good. Continue run 10 3/4" casing filling every joint with Franks fill up toot. Circulate 2 'oints down after eve 10 ran. 12:00 14:45 2.75 1,250 2,642 SURFA CASIN( RNCS P Continue run 10 3!4" casing filling every joint with Franks fill up tool. Circulate 2 joints down after every 10 ran. Circulate down joints # 63 & 64 (2514' - 2596'). Pick up landing joint with vetco Gray casing hanger. Change out anti rotation handling sub. Land 10 3/4" casing with hanger. Shoe de th = 2642.83' MD TVD = 2252'. 14:45 15:15 0.50 2,642 2,642 SURFA CEMEt~ RURD P Rig down GBR casing crew. Clean & clear floor of all running tools. R nxate c~sin stri 15:15 16:15 1.00 2,642 2,642 SURFA CEME~ RURD P Rig up and install 10 3/4" cement head in landin 'oint. Ri u lines. 16:15 16:30 0.25 2,642 2,642 SURFA CEMEt~ CIRC P Break circulation @ 4 BPM- 130 PSI. UP WT = 190K, SO WT = 130K. Increase pump rate to 5 BPM - 190 PSI. Observed O ring failed in cement head. Shut down um s, land han er. 16:30 18:00 1.50 2,642 2,642 SURFA CEME~ RURD T Rig down cement head & change out O ring in cement head. Make up cement head & lines. Crew Chan e. ___.. ~ a.ee.~_ __ ___~_ ._.~®®~~.a._ ®..®~ e_~~ m~_.w_~_. i e " `,~E„ ~ C3~ ~3 ___ _ _ Time Logs Date From To Dur S. E Depth Phase Code Subcode T __ _._ _ 08/27/2006 18:00 20:00 2.00 2,642 2,642 SURFA CEMEf~ CIRC P Circulate & condition mud to pre cement properties of 9.6 PPG, Visc = 50, PV = 22, YP = 15, with Gels @ 6/8. Reciprocate casing string. UP WT = 195K, SO WT = 140K. Held PJSM with entire rig team, truck drivers and cement crew. Discuss safety issues, hazard recognition and procedure to rig u and um surface cement 'ob. . 20:00 22:30 2.50 2,642 2,642 SURFA CEMEf~ CIRC P Turn rig over to Dowell Schlumberger cement crew. Pump 5 BBIs fresh water to flush lines. Pressure test lines to 3500 PSI -good test. Pump 50 BBIs of 8.3 PPG CW100 @ 6 BPM - 150 PSI. Pump 50 BBLS of 10.5 PPG MudPush II with Red Dye @ 5 BPM - 180 PSI. Drop bottom plug. Continue pump 389.4 BBLS of 10.7 PPG Lead cement @ 6.2 BPM - 225 PSI. Stop movement ofi casing string, anct land in hanger 320 BBLS in fo pumping Lead cement. Pump 76 BBLS of 12.0 PPG Tail cement @ 5.6 BPM - 275 PSI. Drop Top Plug. Pump 20 BBLS of fresh water for rinse & flush. Reciprocate casing string. UP WT = 220K, SO WT = 145K. 22:30 23:30 1.00 2,642 2,642 SURFA CEMEf~ DISP P Turn over to rig pumps. Displace cement job with 9.6 PPG mud, observing red dye to surface @ 125 strokes into displacement. Observe cement @ surface @ 1258 Strokes in to displacement. Pumps @ 7 BPM for 1175 stks. 6 BPM for 1380 stks, slowing to 5 BPM to 2148stks. Slow pumps to 3.5 BPM - 500 PSI to observe plugs bumped @ 2246 strokes, (226.17 BBLS). pressure to 1150 PSI. Hold pressure 5 minutes. Bleed pressure & check floats. Floats held. CIP @ 2300 HRS, R~apnocat~t csg 10'-15' until 6"'6 tibls cement around shad, thin csg tigf# eland same on hanger, Had 99.3 bbls good ce ~ surface. 23:30 00:00 0.50 2,642 0 SURFA CEME~ RURD P Rig down cement lines on rig floor. Rig down cement head, blow down all lines. Clean & flush all lines & valves & cement a ui ment. 08/28/2006 00:00 01:45 1.75 0 0 SURFA CEME~ KURD P Rig down cement head & lines. Flush Diverter riser & flow lines with rinsate from truck. P..~__-~ .m..._...~.. ~_... .a~~~ _,a ~®~. ~__~ .....~..~ mw~ .....6~~ ~.m...m Time Logs _ Date From To DLIr S. E. De th Phase Code Subcode T e!. 08/28/2006 01:45 04:00 2.25 0 0 SURFA WELCT NUND _ P Nipple down Diverter system. Remove Riser, and nipple down lines outside. Rig down long bales on top drive. Lay down spiders. Rig off of Hi -Line power and on Cat power @ 0330 HRS, to remove all Diverter equipment, and install wellhead a ui ment. 04:00 06:00 2.00 0 0 SURFA WELCT NUND P Continue nipple down Diverter system. Rinse Annular & lines with rinsate using vac truck. Remove Diverter system adapter flange as per Vetco Gray rep. SIMOPS: Work on Top drive Shot Pin assembly and Brake. Varco re on ri floor. 06:00 08:15 2.25 0 0 SURFA RPCOh NUND P Clean out cellar box, Install Vetco Gray well head as per rep. Rig up & test wellhead seal to 5000 PSI, for 15 minutes - ood test. 08:15 08:45 0.50 0 0 SURFA WELCT NUND P Install double block drilling valve for annular. 08:45 12:00 3.25 0 0 SURFA WELCT NUND P Held PJSM with crew. Discuss safety issues and procedure for nippling up BOP's. Nipple up BOP's .Crew Chan e 12:00 18:00 6.00 0 0 SURFA WELCT NUND P Held PJSM with crew. Discuss safety issues and procedure for nippling up BOP's. Continue Nipple up BOP's . Install Koomey lines, kill lines, and choke line. Install 3 1/2" VBR's in top set of rams, and 7 5/8" rams in lower set of rams. SIMOPS: Begin changing Saver sub on To Drive. 18:00 20:30 2.50 0 0 SURFA WELCT OTHR P Continue change out saver sub on Top Drive. Remove 4 1/2 IF sub, Install 4" XT39 sub. Load pipe shed with 120 'oints of 4" XT39 drill i e. Stra same. 20:30 00:00 3.50 0 0 SURFA DRILL PULD P Held PJSM with crew. Discuss safety issues and procedure for picking up 4" DP and building stands & racking in derrick. Pick up 40 joints of 4" DP from pipe shed. Note: New crew being trained on proper operation of new ST80 iron rou hneck. Crew Chan e 08/29/2006 00:00 04:00 4.00 0 0 SURFA DRILL PULD P Held PJSM with crew. Discuss safety issues and procedure for picking up 4" DP and building stands & racking in derrick. Pick up 80 joints of 4" DP from pipe shed. Crew Change Rabbit 4" w/ 2.33" rabbit. 04:00 06:00 2.00 0 0 SURFA WELCT BOPE P L/D 4 stands of 5" HWDP. Rig up & test BOP's. Test 4-1/2" IF floor safety valve and dart valve to 250 psi low and 3000 si hi h. Hold each test 5 min. 06:00 08:00 2.00 0 0 SURFA WELCT NUND P PJSM, then PU and install riser, install flowline and ad'ust turnbuckles. 08:00 09:00 1.00 0 0 SURFA WELCT OTHR P RU to test ROPE. Fill stack w/water. _ ®~ ®®~ .~ _ ___~ ®m _~ ._ _.__~~~ ~ _..~ ~ ®e..... ~ e ®. ~ ~_mm~~ i ~ __.,_~ ~ ~~e_m._..e_____ ®®v. ~___., _ e® ~__..__ ~. __ ~ ._ , ~ _a__ .....e.. Time Logs - ~ -Date From To Dur S. E Depth Phase Code Subcode T _ 08/29/2006 09:00 16:15 7.25 _ 0 0 SURFA WELCT BOPE P Test BOPE to 250 psi low and 3000 psi high. Tested bottom pipe rams w/ 7-5/8" test jt. Test upper pipe rams (3-1/2" x 6") w/ 4" dp & 5" dp. Test annular w/ 4" dp. Tested all valves on choke manifold and kill and choke valves. Tested top drive IBOP. Witness of test waived by AOGCC inspector Chuck Sheave. 16:15 17:30 1.25 0 0 SURFA WELCT OTHR P Rig down testing equipment. Pull test plug. Install Vetco/Gray wear ring (10.75" OD x 9.9" ID, length 4.92'). Blow down choke manifold and Gill and choke lines. 17:30 17:45 0.25 0 SURFA DRILL SFTY P PJSM on PU/MU BHA #2. 17:45 20:45 3.00 0 446 SURFA DRILL PULD P PU/MU BHA #2 to 446'. MU Hughes 9-7/8" EP5848 bit w/ (3) 20/32 and (1) 12/32 nozzle, 7" Sperrydrill lobe 7/8-6 stage motor w/ 1.5 deg bend, nm float sub, welded blade stabilizer, MWD DM HOC, MWD Gamma/Res/PWD, MWD TM HOC, (3) 6-7/8" NM drill collars, (3) 5" HWDP, Drilling jar (6.2" OD), (5) 5" HWDP. 20:45 21:45 1.00 446 2,452 SURFA DRILL TRIP P RIH w/ BHA #2 f/ 446' to 2452'. Total of 21 stands of Weatherford 5" dp in hole. Installed Ghost reamer on top of stand #4. 21:45 22:15 0.50 2,452 2,452 SURFA DRILL OTHR P Change elevators to 4". Install bell uide f/ 4" d on to drive. 22:15 23:00 0.75 2,452 2,548 SURFA DRILL CIRC P Make top drive connection on stand #22. Fill pipe. Circulate bottom's up. Pumping 140 spm w/ 1850 psi. Pump 2200 strokes. Rotate 50 rpm w! 5-6k ft Ibs for ue. Shallow test MWD. 23:00 23:45 0.75 2,548 2,548 SURFA DRILL DHEO P Test 10-3/4" 45.5 ppf, L-8U BTC to 3i~ .: Chat t+e~t ~txt l fi 30 rain. 23:45 00:00 0.25 2,548 2,559 SURFA CEMEI~ CIRC P MU top drive to stand #23. Establish circulation. PU wt 145k, SO wt 110k, Rot wt 128k. Rotate 50 rpm w/ 5-6k ft Ib torque, pumping 149 spm (633 gpm) w/ 1970 psi off bottom, 2040 psi on bottom. Prepare to drill wiper plugs and then float collar 2559.78' 08/30/2006 00:00 01:45 1.75 2,652 2,672 SURFA CEME-~ DRLG P MU top drive to stand #23. Establish circulation. PU wt 145k, SO wt 110k, Rot wt 128k. Rotate 50 rpm w/ 5-6k ft Ib torque, pumping 149 spm (633 gpm) w/ 1970 psi off bottom, 2040 psi on bottom. Drill wiper plugs and then float collar @ 2559.78', cement, FS 2642', rat hole to 2652', then 20' new hole to 2672' (2276' TVD). Drill w/ 10k WOB. Bit hrs .12 hrs, jar hrs 39.08 hrs. ~ ~~~~~ _' i - Time Logs- - - _ Date Froi~~ To Dur S. D E. Depth Phase Code Subcode T C 08/30/2006 01:45 02:15 0.50 2,672 2,672 SURFA CEME~ CIRC P Circulate and displace mud to new 9.0 ppg LSND. Circ BU after displacement.Pumping 150 spm (634 gpm) w/ 1660 psi. Baseline clean hole ECD is 9.27 02:15 02:45 0.50 2,672 2,645 SURFA CEME~ LOT P Stand back stand # 24 after drilling 27' to 2672'. Perform LOT w/ 9.1 ppg mud. 502 psi, csg shoe @ 2642' (2252' TVD). E~AW = 13.4 PPG. Hrs on bit .12 hrs 02:45 03:00 0.25 2,645 2,645 INTRM1 DRILL OTHR P Bleed off pressure. Blow down top drive. Threads on saver sub are ailed. 03:00 06:00 3.00 2,645 2,672 INTRM1 DRILL OTHR T Change out saver sub on top drive. Check connections which were screwed into. Replace top jt on stand #23, replace top and bottom jts of stand # 24. Corrected i e tall . 06:00 08:00 2.00 2,672 2,829 INTRMI DRILL DDRL P Drilling 9-7/8" intermediate from 2672' (2276' TVD) to 2829' (157') (2391' TVD) Bit hours= .99, Jar hours= 39.97, AST=.00 hrs, ART=.87 hrs, ADT=.87 hrs, WO6= 10-15k, 60-80 rpm, Mtr rpm 210-214, 636-650 gpm @ 1750-1770 psi on bottom and 1700 psi off bottom. Torque = 5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.42 ppg. P/U = 140-145k, S/O = 115-120k, Rot= 130k w/ pump off. 08:00 09:00 1.00 2,829 2,829 INTRM1 DRILL OTHR T Trouble shoot surface equipment (Mud pump, etc.). Having problems getting detection f/ surveys. Clean suction screens on both mud pumps. Lower pressure in discharge pulsation dampners. SPR's: #1 @ 20 spm = 120 psi, 30 spm = 180 psi. #2 mp @ 20 s m = 120 si, 30 s m = 180 si. 09:00 09:15 0.25 2,829 2,829 INTRM1 DRILL OTHR T Mode switch MWD tool. Appears to be workin . 09:15 12:00 2.75 2,829 3,160 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 2829' (2391' TVD) to 3160' (331') (2640' TVD) Bit hours= 2.94, Jar hours= 41.92, AST=.1.11 hrs, ART=..84 hrs, ADT= 1.95 hrs, WOB= 5-15k, 80 rpm, Mtr rpm 214, 650 gpm @ 1770-2000 psi on bottom and 1700-1950 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.4-9.5 ppg. P/U = 145-160k, S/O = 115-120k, Rot= 130-135k w/ um off. ®.-_ _ _ ~.. _..~® ®eme e®m~~-__~ Time Logs -- _ -- - -- - --~ Date From To Dur S. D E. De th Phase Code Subcode T C 08/30/2006 12:00 18:00 6.00 3,160 3,888 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 3160' (2640' TVD) to 3888' (331') (3143' TVD) Bit hours= 6.62, Jar hours= 45.60, AST= 2.63 hrs, ART=1.05 hrs, ADT= 3.68 hrs, WOB= 10-15k, 80 rpm, Mtr rpm 205-214, 623-650 gpm @ 1970-2350 psi on bottom and 1940-2300 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.6-9.84 ppg. Gas units = 14. P/U = 155-160k, S/O = 120-125k, Rot= 135-140k w/ pump off. Pump 25 bbls hi vis sweep while drilling @3679' (3092' TVD), no noticable increase in cuttin s. 18:00 00:00 6.00 3,888 4,480 INTRMI DRILL DDRL P Drilling 9-7/8" intermediate from 3888' (3143' TVD) to 4480' (592') (3457' TVD) Bit hours= 10.35, Jar hours= 49.33, AST= 2.41 hrs, ART=1.32 hrs, ADT= 3.73 hrs, WOB= 10-20k, 80 rpm, Mtr rpm 208-211, 636-640 gpm @ 2280-2590 psi on bottom and 2280-2390 psi off bottom. Torque = 4-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.84-9.97 ppg. Gas units = 14 P/U = 153-158k, S/O = 127-125k, Rot= 135-140k w/ pump off. SPR @ 4145' (3299' TVD) #1 mp @ 20 spm = 190 psi, 30 spm=250 psi, #2mp @ 20spm=190 psi, 30 spm=260 Pump 25 bbls hi vis sweep while drilling @ 4425' (3433' TVD}, no noticable increase in cuttin s. 08/31/2006 00:00 06:00 6.00 4,480 4,892 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 4480' (3457' TVD) to 4892' (412') (3564' TVD) Bit hours= 14.6, Jar hours= 53.58, AST= 2.03 hrs, ART=2.22 hrs, ADT= 4.25 hrs, WOB= 10-22k, 80-90 rpm, Mtr rpm 208-211, 636-640 gpm @ 2590-2700 psi on bottom and 2400-2600 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.29-10.02 ppg. P/U = 160-155k, S/O = 125-122k, Rot= 140-135k w/ um off. 06:00 12:00 6.00 4,892 5,406 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 4892' (3564' TVD) to 5406' (514') (3660' TVD) Bit hours= 18.54, Jar hours= 57.52, AST= 1.39 hrs, ART=2.55 hrs, ADT= 3.94 hrs, WOB= 15-20k, 90 rpm, Mtr rpm 210-206, 636-625 gpm @ 2670-2480 psi on bottom and 2590-2200 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 9.87-9.79 ppg. Avg gas 100 units. P/U = 155k, S/O = 125-120k, Rot= 135k w/ um off. I ~ e Time Los - Date From To Dur __S_. D,E. Depth Phase Code Subcode T _ _ 08/31/2006 12:00 18:00 6.00 5,406 5,922 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 5406' (3660' TVD) to 5922' (516') (3742' TVD) Bit hours= 22.47, Jar hours= 61.45, AST= 1.02 hrs, ART=2.91 hrs, ADT= 3.93 hrs, WO6= 15-20k, 90 rpm, Mtr rpm 211-214, 642-650 gpm @ 2720-2800 psi on bottom and 2600-2710 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 9.80-10.4 ppg. Avg gas 30 units. P/U = 155-150k, S/O = 120-115k, Rot= 135k w/ um off. 18:00 18:15 0.25 5,922 5,926 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 5922' (3742' TVD) to 5926' (4') (3742' TVD) Bit hours= 22.50, Jar hours= 61.48, AST= .03 hrs, ART= O.Ohrs, ADT= .03 hrs, WOB= 15-20k, 90 rpm, Mtr rpm 214, 650 gpm @ 2800 psi on bottom and 2710 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 10.4 ppg. P/U = 155k, S/O = 115k, Rot= 135k w/ um off. 18:15 19:00 0.75 5,926 5,833 INTRM1 DRILL CIRC P Set back a stand. SPR's and Pump Hi vis weighted sweep (10 ppg, 250 vis}, while backreaming slow f/ 5926' to 5833'. Pumping 650 gpm w/ 2800 psi, rotating 90 rpm w/ 7k ft Ib torque. No noticable increase in cuttin s. 19:00 00:00 5.00 5,833 3,390 INTRM1 DRILL REAM P Continue backreaming out of hole f/ 5833' to 3390. Pumping 650 gpm w/ 2800- 2200 psi. ECD's 11.01 max. ECD's @ 3390' 10.44 ppg. Pulling @ 40-45 ft/min. 09/01/2006 00:00 00:30 0.50. 3,390 3,000 INTRM1 DRILL REAM P Continue backreaming out of hole f/3390 to 3000'. Pumping 650 gpm w/ 2200-1800 psi. ECD's 10.44 max. Pullin 40-45 ft/min. 00:30 01:30 1.00 3,000 2,800 INTRMI DRILL REAM P Hole unloading lots of clay. Continue backreaming out of hole f/3000' to 2800'. Pumping 650 gpm w/ 1800 psi. ECD's 10.44 max. Slowed pulling s eed to 15 ft/min. 01:30 02:15 0.75 2,800 2,520 INTRM1 DRILL REAM P Continue backreaming out of hole f/2800' to 2520'. Pumping 650 gpm w/ 1800- 1600 psi. ECD's 10.44 to 9.8 ppg. Increased pulling speed to 35-45 ft/min. 02:15 03:30 1.25 2,520 2,520 INTRM1 DRILL CIRC P Circ to clean up mud in casing. Initial ECD's 9.8 ppg, final 9.32 ppg. Circ @ 650 gpm w/ 1600 psi while working pipe. Rotating 60 rpm. Circ 9.7 ppg 245vis sweep, follow till mud in good shape to run casing. Final MW 9.0= in and out. 03:30 04:00 0.50 2,520 2,520 INTRM1 DRILL OWFF P Monitor well. OK. Pump dry job, blow down to drive. s ..®. 4. ~ A r 4 bi tY I Time Logs _ _ _ ___ Date From To Dur S..~ E Depth Phase Code Subco de~~ 09/01/2006 04:00 __ _ 04:15 0.25 2,520 2,454 INTRM1 DRILL _ TRIP P _ __ Pull and stand back last stand of 4" dp, remove crossover. Change elevators to 5" 04:15 05:30 1.25 2,454 450 INTRM1 DRILL TRIP P POOH/stand back 5" dp f/ 2454' to 450'. La ed down 9-7/8" host reamer. 05:30 06:00 0.50 450 80 INTRM1 DRILL TRIP P Stand back 3 stands of 5" HWDP w/ 'ars.. UD Flex dc's. 06:00 06:45 0.75 80 80 INTRM1 DRILL OTHR P Download Sperry Sun MWD. 06:45 08:00 1.25 80 0 INTRM1 DRILL PULD P Finish UD BHA #2. 08:00 09:00 1.00 0 0 INTRM1 DRILL OTHR P Rig up and pull wear bushing. 09:00 09:15 0.25 0 0 INTRM1 CASIN( SFTY P PJSM on rigging up to run 7-5/8" intermediate casin . 09:15 10:45 1.50 0 0 INTRM1 CASIN( RURD P ~ Rig up to run 7-5/8" casing w/GBR casin tools and Frank's fillu tool. 10:45 11:00 0.25 0 0 INTRM1 CASIN( SFTY P PJSM on running 7-5/8", 29.7 ppf, L-80 BTC casing w/ rig crew and GBR casin crew. 11:00 15:30 4.50 0 2,640 INTRM1 CASIN( RNCS P Run 7-5/8" casing: MU Weatherford model 303 float shoe, 2 jts , Weatherford model 402 float collar, 18 jts, One joint f/ "B" sand window, 6 jts, a 20' pup, one jt f/ "D" sand window, then to jt # 62 in hole to 2640'. Ran tandem rise(TR2) centralizers 3/2 jts on first 30 jts. Then run TR2 centralizers on collars of #31 to #54. Ran total of 62 tandem rise and 28 sto s. 15:30 15:45 0.25 2,640 2,640. -NTRM1 CASIN( CIRC P Circ BU (101 bbls) @ 2645' (inside 10-3/4" casing). Circ 4-6 bpm w/ 230-330 si. 15:45 19:30 3.75 2,640 5,890 INTRM1 CASIN( RNCS P Continue running 7-5/8" 29.7 ppf L-80 BTC-mod casing f/ 2640' to 4750' (jt # 111), break circ, run casing f/ 4750' to 5115' (jt # 120), break circ, run casing f/ 5115' to 5840' (jt # 137, break circ, run casin f/ 5840' to 5890' 't # 138 . 19:30 19:45 0.25 5,890 5,926 INTRM1 CASIN( RNCS P MU Jt # 139, circulate jt down to 5926'. 19:45 20:30 0.75 5,926 5,926 INTRM1 CEME~ RURD P Remove Frank's fillup tool, blow down to drive, install Dowell cement head. 20:30 22:45 2.25 5,926 5,926 INTRM1 CEMEt~ CIRC P Circulate prior to cementing. Circulate @ 6 bpm w/ 380 psi. PU wt 200k and SO wt 140k after circ. Circulated total of 740 bbls prior to cementing. Held PJSM w/ cementing crew and APC truck drivers while circulating. Mud properties before : 8.9ppg, 44 vis, 9/17 PV/YP. Mud properties after conditioning : 8.9ppg, 40 vis, 9/15 PV/YP. Reci i e 5' er min, 30' stroke. ~m~~. ~.. ~ _ _ .~ _ ~~~_ . _ _._ ~~ _.~~ ~ _~~__.___® _®. ns __ _____~ n.. ~~ ~° E Time Logs ~~~-~ -~~ ~~~ _ _ ___ Date Fror~i To Dur S. D E. De th Phase Code Subcode T 09/01/2006 22:45 00:00 1.25 5,926 5,926 INTRM1 CEME~ OTHR P Dowell, pump 10 bbls CW100, test lines to 3500 psi, pump @ 5 bpm w/ 220- 330 psi (40 bbls CW100), mix and pump @ 5 bpm w/ 320-220 psi (72.6 bbls MudPush II) @ 11.0 ppg, drop bottom plug, mix and pump @ 4.4 bpm w/ 235-100 psi (138.9 bbls DeepCrete) @ 12.5 ppg, drop top plug, Dowell kick out plug w/ 5 bbl water. Reci i e 5'/min, 30' stroke. 09/02/2006 00:00 00:45 0.75 5,926 5,920 INTRM1 CEMEI~ DISP P Displace cement with rig pumping 8.9ppg OBM @ 6 bpm until last 9 bbls then slow down to 3 bpm. Initial pressure 100 psi, final @ 3bpm was 850 psi. Bump plug @ calc strokes (2602) w/ 1400 psi. CIP @ 0045 hrs 9/2/2006. Continue recip 7-5/8" casing 5'/min 30' stroke while displacing cement w/ OBM. Recip until last 25 bbls pumped. Final PU wt 170k, SO wt 100-110k. Float shoe 5920'. 00:45 02:15 1.50 5,920 5,920 INTRM1 CEME~ RURD P Bleed off pressure, check floats, OK. Blow down cement line. hang cement hose in derrick. Remove Dowell cement head. Drain stack. Vacum out landin 't. 02:15 02:30 0.25 5,920 5,920 INTRM1 DRILL OTHR P PJSM on picking up stack and setting slips w/ Vetco Gray and Tourpusher and crew. 02:30 03:00 0.50 5,920 5,920 INTRM1 WELCT NUND P Break Vetco Gray multibowl, PU BOP stack. 03:00 04:30 1.50 5,920 5,920 INTRM1 WELCT OTHR P Install Vetco Gray 7-5/8" slips. Slack off on slips w/ 180k on weight indicator. Blocks = 70k. Cut off 7-5/8" casing. dress cut on jt # 138. Lay down landin 't w/ 11' cutoff f/ 't # 138. 04:30 05:00 0.50 5,920 5,920 INTRM1 WELCT OTHR P Install Vetco Gray packoff. Tighten lockdown screws to 580 ft lbs. 05:00 06:15 1.25 0 0 INTRM1 WELCT NUND P Set BOP's and Vetco Gray multibowl back down. Tighten break on multibowl. 06:15 06:45 0.50 0 0 INTRM1 WELCT BOPE P Testing 7-5/8" packoff and break on Vetco/Gray Multibowl to 250 psi low and 3850 si hi h f/ 10 min each. OK. 06:45 08:45 2.00 0 0 INTRM1 DRILL LOT P Continue laying down casing tools. RU & perform LOT on 10-3/4" x 7-5/8" Annulus. EMW of fluid in annulus is 9.7 ppg (11.Oppg mudpush II and 8.36ppg CW100, 9.0 ppg mud). 200 psi @ TVD of 2252' at the 10-3/4" casing shoe = 11.4 ppg EMW. After test, pump 30 bbls fresh water to flush annulus of ossible cement. 08:45 09:15 0.50 0 0 INTRMI DRILL OTHR P Install Vetco Gray wear bushing. 10.5" OD, 6-7/8" ID x 3.45" Ion . ~ ®.. ~ ~~ ~~ ~~ wm.. ® ea ~. _ ~~ ®~ ~ ....a~ _ ~~e®Aa~~_ _~.. ~-~_~- °'r. Time Logs.. _ Date From To Dur S. D E. De th Phase Code Subcode T 09/02/2006 09:15 10:00 0.75 0 0 INTRM1 WELCT NUND P Nipple up flowline, install and tighten turnbuckles on BOP stack. 10:00 10:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up Weatherford 4" drill pipe w/ Western Well Tools super sliders from i e shed. 10:15 11:15 1.00 0 0 INTRM1 DRILL PULD P PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools super sliders. Flush 10-3/4" x 7-5/8" annulus w/ 120 bbls water 2.5 b m w/ 670 si. 11:15 13:00 1.75 0 0 INTRM1 DRILL PULD P PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools su er sliders. 13:00 16:15 3.25 0 3,720 INTRM1 DRILL PULD P Continue PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools super sliders. Total of 120 jts (40 stands) of 4" pipe w/ super sliders picked up a rox 3720' 16:15 16:45 0.50 3,720 3,720 INTRM1 DRILL CIRC P Pump @ 4bpm w/ 360 psi to clean out drill pipe. Note: Little Red pumping 80 bbls of diesel into 10-3/4" x 7-5/8" annulus f/ freeze protection. Pressure test to 2500 psi. pump @ 2bpm w/ 1000 psi. Final ressure 750 si after um in . 16:45 18:00 1.25 3,720 2,883 INTRM1 DRILL TRIP P POOH wet w/ 4" drill pipe w/ super sliders, rack back on off driller's side of derrick. 9 stands out @ 1800 hrs, approx depth 2883'. All mud its are cleaned. 18:00 18:30 0.50 2,883 2,325 INTRM1 DRILL TRIP P Continue POOH wet w/ 4" dp w/ super sliders f/ 2883' to 2325'. Rack on off driller's side. 18:30 19:00 0.50 2,325 2,325 INTRM1 DRILL CIRC P Crew change, pump dry job. Blow down to drive. 19:00 21:00 2.00 2,325 0 INTRM1 DRILL TRIP P Continue POOH wet w/ 4" dp w/super sliders f/ 2325' to all 40 stands out of hole. Rack on off driller's side. 21:00 23:15 2.25 0 0 INTRM1 DRILL OTHR P Getting 4" dp in pipe shed, strap and read to PU. 23:15 23:30 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up 5" DC's and 4" HWDP to build H brids. 23:30 00:00 0.50 0 0 INTRM1 DRILL PULD P PU/MU Hybrids (2 jts of Weatherford (5" OD x 2/58" ID) DC's w/ jt of 4" HWDP on top). MU in mouse hole, stand back in derrick on driller's side. Rabbit w/ 2.33" OD rabbit. 4 stands of total of 15 to be picked up, in derrick midni ht. 09/03/2006 00:00 02:15 2.25 0 0 INTRM1 DRILL PULD P Continue PU/MU Hybrids (2 jts of Weatherford (5" OD x 2/58" ID) DC's w/jt of 4" HWDP on top). MU in mouse hole, stand back in derrick on driller's side and off driller's side. Rabbit w/ 2.33" OD rabbit. 10 stands on driller's side, 5 stands on off driller's side. m~. e .® ~~ ~ ~ ®. ~ a ~ ....~.~ _~~_ _ ~ ~m ~~,vmm ~.._ _ _e ~.® .m .,_.~ .__.....-._ s~ ____.__. _ ~ m. ~._~ _~®_R_~___ _, m ~~m~~ ~.~.~_. ~ m,_...__~ a~ - - - -----_ - ~, TimeLo~ Date From To Dur S. D E. De th Phase Code _ Subcode T _ ______ _ 09/03/2006 02:15 03:00 0.75 0 0 INTRM1 DRILL PULD P Pu/MU/ Standback in derrick 4 stands of Weatherford 4" HWDP. 03:00 04:45 1.75 0 126 INTRM1 DRILL PULD P PU/MU BHA # 3: Security 6-3/4" FMF 3641 Z bit w/ (3) 21 /32's (TFA 1.015), SperrySun geoPilot 5200 (ser # TL019}, geoppilot flex collar, SperrySun 4-3/4" DIR, smart stab, gamma/res, pwd, tm hoc, nm flaot sub, welded blade stab, (1) 4-3/4" NM DC. to 126' 04:45 05:15 0.50 126 51 INTRM1 DRILL OTHR P Upload MWD tools. 05:15 06:00 0.75 51 285 INTRM1 DRILL PULD P Continue PU/MU BHA #3: PU (2) 4-3/4" nm DC's, x-o, (1) 4" HWDP, DNT 'ars, 1 4" HWDP to 285'. 06:00 06:15 0.25 285 285 INTRM1 DRILL DHEQ P Pulse test MWD tool. Pumping 300 gpm w/ 1300 psi. Break in seals on eoPilot. 06:15 12:00 5.75 285 3,752 INTRM1 DRILL PULD P PU/MU 111 jts of 4" dp f/ shed. Rabbit to 2.33". 12:00 13:15 1.25 3,752 4,409 INTRM1 DRILL PULD P Continue PU/MU BHA #3: DNT jars, then rest of 4" dp in pipe shed to 4409'. Back on Hi-Line ower 1300 hrs. 13:15 13:30 0.25 4,409 4,409 INTRM1 DRILL OTHR P Lower skate ramp on rig floor,remove thread protectors, clear and clean rig floor. 13:30 14:15 0.75 4,409 5,724 INTRM1 DRILL TRIP P RIH f/ 4409' to 4771' (3547' TVD), fill pipe. Pumping 300 gpm w/ 2470 psi, 30 rpm, 3-4k ft Ib torque. Continue RIH to 5724' 3711' TVD . 14:15 15:45 1.50 5,724 5,800 INTRM1 DRILL CIRC P While CBU @ 300 gpm w/ 2850 psi, 50 r m, to ed strin ers 5800'. 15:45 16:00 0.25 5,800 5,800 INTRM1 DRILL SFTY P PJSM on tripping in hole. 16:00 16:15 0.25 5,800 5,818 INTRM1 CEMEf~ COCF P MU stand, cleanout to 5818'. 16:15 17:00 0.75 5,818 5,818 INTRM1 RIGMN SFTY P PJSM on changing out drilling line. 17:00 21:45 4.75 5,818 5,818 INTRM1 RIGMN OTHR P Change out 1-3/8" drilling line. Install new line on drum. 21:45 22:15 0.50 5,818 5,818 INTRM1 RIGMN SVRG P Service top drive and drawworks. 22:15 22:45 0.50 5,818 5,818 INTRM1 RIGMN OTHR P Calibrate block height on TOTCO and Sperry Sun computers. TOTCO rep hel ed to ex lain rocedure. 22:45 23:45 1.00 5,818 5,818 INTRM1 CASIN( DHEQ P Test casing to 3000 psi f/ 30 min. Chart test. 23:45 00:00 0.25 5,818 5,832 INTRM1 DRILL CIRC P Establish circulation w/ 298 gpm, 2310 psi, rot 100 rpm w/ 3-4k ft Ib torque. PU wt 150, SO 115k, Rot 125k. Drill f/ 5818' to to of FC 5832'. 09/04/2006 00:00 02:15 2.25 5,832 5,926 INTRM1 CEMEf~ COCF P Drill FC @ 5832', cement, FS top @ 5918.5, rat hole to 5926'. 300- 325 gpm 2400-2650, rotate 100 rpm w/ 5k ft Ib for ue. ;. ------- - Time Logs _ _ Date From To Dur S.D E De th Phase Code Subcode T 09/04/2006 02:15 02:30 0.25 5,926 5,946 INTRM1 _ DRILL DDRL P Drill 20' new hole f/ 5926' to 5946'. Drill w/ 4-6k wob, 300 gpm w/ 2800 psi, rotate 100 rpm w/ 4k ft Ib torque. ART = .10 hrs. Jar # 0043 = 84.67 hrs, Jars 0019 = 175.41 hrs 02:30 03:45 1.25 5,946 5,946 INTRM1 DRILL CIRC P Backream twice, then stand a stand back and finish circulating 480 bbls till hole clean (26U+). Circ 309 gpm w/ 2400 psi, rotate 90 rpm w/ 3-4k ft Ib torque. Obtain baseline f/ ECD's/PWD. 9.75 w/ clean hole-8.8 mud 03:45 04:45 1.00 5,946 5,946 INTRM1 DRILL LOT P Perform LOT. Shoe @ 5920' (3741' TVD), 8.8 ppg mud wt, 1080 psi applied pressure =Leak off @ 14.4 04:45 06:00 1.25 5,946 6,035 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 5946' (3744' TVD) to 6035' (89') (3750' TVD) Bit hours= .95, Jar (#141-0019) hours= 179.91, Jar (#1471-0043) hours = 89.17, Accelerators (#1447-1034) = 179.91 hrs, ART= 0.85hrs, WOB= 6-8k, 90 rpm, 310 gpm @ 2600 psi on bottom and 2400 psi off bottom. Torque = 5k ft-Ibs on botttom and 4k ft-Ibs off bottom. ECD= 9.67 ppg. P/U = 150k, S/O = 115k, Rot= 125k w/ um off. 06:00 12:00 6.00 6,035 6,751 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 6035' (3750' TVD) to 6751' (716') (3721' TVD) Bit hours= 5.45, Jar (#141-0019) hours= 170.76, Jar (#1471-0043) hours = 90.02, Accelerators (#1447-1034) = 180.76 hrs, ART= 4.5 hrs, WOB= 2-8k, 90-130 rpm, 310-347 gpm @ 2600-2880 psi on bottom and 2400-2800 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.67-10.25 ppg. P/U = 150-155k, S/O = 115-10$k, Rot= 125k w/ um off. 12:00 18:00 6.00 6,751 7,403 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 6751' (3721' TVD) to 7403' (652') (3731' TVD) Bit hours= 10.12, Jar (#141-0019) hours= 185.43, Jar (#1471-0043) hours = 94.69, Accelerators (#1447-1034) = 185.43 hrs, ART= 4.67 hrs, WOB= 4-10k, 130 rpm, 347-350 gpm @ 2780-3000 psi on bottom and 2720-2950 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.16-10.3 ppg. P/U = 155-160k, S/O = 115-100k, Rot= 125-120k w/ um off. y --..-~..,_ _ ,.an® ®®. ~e ~t ~m~W m.e..®~. .. M..aa~ ~.®®e. ~.~e - .a..m®®.-®. .e..a ~...... ..tee.. ... ®®, s ..~--.- ..... .. ... ....f i .... ~ ~.~.. ..................... ... ~.®,,. _. ~......,...... sue...... ,,,,,,m m.e......, ~..b --- Time Logs - >~--- --- ~ Date From To Dur S. D E. nth Phase Code Subcode T _ _ _______ 09/04/2006 18:00 00:00 6.00 7,403 7,979 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 7403' (3731' TVD) to 7979' (576') (3724' TVD) Bit hours= 14.6, Jar (#141-0019) hours= 189.91, Jar (#1471-0043) hours = 99.17, Accelerators (#1447-1034) = 189.91 hrs, ART= 4.48 hrs, WO6= 2-10k, 130 rpm, 350 gpm @ 3000-3250 psi on bottom and 2950-3250 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-11.01 ppg. P/U = 155-160k, S/O = 100-95k, Rot= 125-122k w/ um off. 09/05/2006 00:00 01:15 1.25 7,979 8,159 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 7979' (3724' TVD) to 8159' (180') (3731' TVD) Bit hours= 15.33, Jar (#141-0019) hours= 190.64, Jar (#1471-0043) hours = 99.9, Accelerators (#1447-1034) = 190.64 hrs, ART= .73 hrs, WO6= 2-10k, 130 rpm, 350 gpm @ 3250 psi on bottom and 3250 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-11.01 ppg. Avg gas 20 units.P/U = 155-160k, S/O = 100-95k, Rot= 125-122k w/ pump off. 01:15 01:30 0.25 8,159 8,159 PROD1 DRILL REAM T PJSM on backreaming out of hole f/ sidetrack. 01:30 02:30 1.00 8,159 7,780 PROD1 DRILL REAM T Backream out of hole f/ 8159' (3731' TVD) to 7780' (TVD= 3731') f/ sidetrack. Out of A2 sands. Pumping 350 gpm w/ 3200 psi, rotating 130 rpm w/ 4k ft Ib torque. PU wt 160k, SO wt 100k. Pulling seeded 40-45 ft/min. ECD's were 11.01 ppg, final ECD's 10.48 02:30 06:15 3.75 7,780 7,675 PROD1 DRILL REAM T Troughing f/ openhole sidetrack @ 7780' 7800'. Pumping 350 psi w/ 3000 psi. Rotate 120 rpm w/ 5-6k ft Ib torque. ECD's 10.11 ppg. WOB 0-2k. Set back a stand. 06:15 08:30 2.25 7,675 7,710 PROD1 DRILL REAM T Trough f/ 7675' to 7710' (3734' TVD) f/ o en hole sidetrack. 08:30 10:30 2.00 7,710 7,757 PROD1 DRILL OTHR T Time drill f/ 7710' to 7757' (3733' TVD). 350 gpm w/ 3000 psi. Rotate 120 rpm w/ 5-6k ft Ib for ue. ECD's 1011 10:30 11:00 0.50. 7,757 7,757 PROD1 DRILL OTHR T Lost Hi-line power. Start engines. Start shakers and air compressors. Start mud um s, re ain circulation. s~._ ~ _.a..m. ®.e _~. _ ... m~ ~ ~m~ ~m~® ~ _ _~~~em... A~-__ __~ .® ~e....s - _ame~ ~ _ _~~~ ~ ~- 1 1 P~ Time Logs Date From To Dur S. D E. De th Phase Code Subcode T 09/05/2006 11:00 12:00 1.00 7,757 7,825 PROD1 DRILL OTHR T _ Drilling sidetrack hole 6-3/4" production A2 lateral f/ 7757' (3733' TVD) to 7825' (68') (3732' TVD) Bit hours= 18.12, Jar (#141-0019) hours= 193.43, Jar (#1471-0043) hours = 102.69, Accelerators (#1447-1034) _ 1193.43 hrs, ART= 2.79 hrs-- includes time drilling & troughing, WO6= 2-8k, 130 rpm, 350 gpm @ 3150-3250 psi on bottom and 3080-3170 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.5-10.24 ppg. P/U = 160-162k, S/O = 95-105k, Rot= 125k w/ pump off. 12:00 13:00 1.00 7,825 8,159 PROD1 DRILL OTHR T Drilling sidetrack hole 6-3/4" production A2 lateral f/ 7825' (3732' TVD) to 8159' (334') (3741' TVD) Bit hours= 19.12, Jar (#141-0019) hours= 194.43, Jar (#1471-0043) hours = 103.69, Accelerators (#1447-1034) _ 1194.43 hrs, ART= 1 hrs, WO6= 2-8k, 130 rpm, 350-310 gpm @ 3250-2800 psi on bottom and 3170-2710 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-9.98 ppg. P/U = 160k, S/O = 100k, Rot= 125k w/ um off. 13:00 17:30 4.50 8,159 8,401 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8159' (3741' TVD) to 8401' (242') (3739' TVD) Bit hours= 21.88, Jar (#141-0019) hours= 197.19, Jar (#1471-0043) hours = 106.45, Accelerators (#1447-1034) = 1197.19 hrs, ART= 2.76 hrs, WO6= 8-14k, 130 rpm, 350 gpm @ 3400 psi on bottom and 3400 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 9.98-10.6 ppg. P/U = 160-165k, S/O = 100k, Rot= 125k w/ um off. 17:30 18:30 1.00 8,401 8,160 PROD1 DRILL TRIP T Geopilot is drilling left when it says it is drilling right. Pump out of hole f/ 8401' to 8160', taking check shot surveys. Pumping 340 gpm w/ 3000 si. PU wt 160k, SO wt 100k. 18:30 18:45 0.25 8,160 8,160 PROD1 DRILL SFTY T Elevators contacted platform (Diving board) @ derrick board. Picked board u 6-8". Check out board. OK. 18:45 19:15 0.50 8,160 7,875 PROD1 DRILL TRIP T Continue pumping out f/ 8160' to 7875'. Pum in 340 m w/ 3000 si. 19:15 20:30 1.25 7,875 6,660 PROD1 DRILL TRIP T Pull out of hole on elevators f/ 7875' to 6660' wet while mixing a dry job. PU wt 165k, SO wt 109k. 20:30 21:00 0.50 6,660 6,660 PROD1 DRILL CIRC T Monitor well. Pump dry job, line up on tri tank. Check crown-o-matic. m e.e~~., . ~ ®.~_~ ~ .m..m. ~ _~_-_-__._v~~ se_~ ..~ -~~ m.m .e~ _ ~~s.® ---_v.me~as w..... ,.m~~_ ~_~ ~_ ~` Time Logs ------- - - - _ - Date From To Dur S. D E Depth Phase Code Subcode T L r 09/05/2006 21:00 00:00 3.00 6,660 1,977 PROD1 DRILL TRIP T POOH f/ 6660' to 1977'. Record PU and SO wt's every 5 in open hole and every 10 stands in cased hole. PU wt 115k, SO wt 105k. 09/06/2006 00:00 01:00 1.00 1,977 348 PROD1 DRILL TRIP T POOH f/ 1977' to 348'. Record SO wt's eve 10 stands in cased hole. 01:00 01:45 0.75 348 92 PROD1 DRILL TRIP T Standback HWDP and BHA #3 to S er Sun MWD tools. 01:45 02:30 0.75 92 92 PROD1 DRILL OTHR T Plug in, download data f/MWD. Break bit. 02:30 04:00 1.50 92 0 PROD1 DRILL PULD T UD Geopilot ser # TL019, PU GeoPilot # TL018, change out directional collar, MU new bit. 04:00 04:45 0.75 0 92 PROD1 DRILL OTHR T Upload Sperry Sun MWD tools. 04:45 05:15 0.50 92 348 PROD1 DRILL TRIP T RIH w/ BHA #4, f/ 92' to 348'. 05:15 09:30 4.25 348 5,900 PROD1 DRILL TRIP T Continue RIH w/ BHA #4 f/ 348' to 5900'. 09:30 10:00 0.50 5,900 5,900 PROD1 DRILL CIRC T Fill pipe. Circ 280 gpm (66 spm) w/ 2010 si. Pum ed 48 bbls. 10:00 10:15 0.25 5,900 5,900 PROD1 DRILL OTHR T Monitor well. Blow down top drive. 10:15 10:30 0.25 348 348 PROD1 DRILL OTHR T Shallow test MWD tools. Break in seals on geopilot. Send downlink to eo ilot. 10:30 13:00 2.50 5,900 5,900 PROD1 RIGMN SVRG P Change out saver sub on top drive. Service ri . 13:00 14:15 1.25 5,900 7,600 PROD1 DRILL TRIP T RIH w/ BHA #4 from 5900' to 7600'. 14:15 14:30 0.25 7,600 7,600 PROD1 DRILL CIRC T Fill pipe. Break circulation. 14:30 15:30 1.00 7,600 7,640 PROD1 DRILL DDRL T Trough for open hole sidetrack #2. Trough 7600' to 7640'. Pumping 350 gpm w/ 3100 psi. Rotate 130-150 rpm w/ 5k ft Ib for ue. 15:30 17:30 2.00 7,640 7,640 PROD1 DRILL DDRL T Attempt to sidetrack @ 7640'. Survey showed no sidetrack. Start over @ 7640' time drillin . 17:30 18:00 0.50 7,600 7,600 PROD1 DRILL CIRC T Time drill f/ 7600'. No detection w/ MWD while time drilling. Loss of pump pressure over time. Totco showed #2 mp --82 psm @ 1430 hrs= 3250 psi, @ 1800 hrs 2550 psi. Difference of 700 si. 18:00 19:00 1.00 7,600 7,600 PROD1 DRILL OTHR T Check pumps and surface equipment for loss of ressure. All OK. 19:00 22:15 3.25 7,600 3,784 PROD1 DRILL TRIP T POOH wet w/ BHA #4, looking for washout. Found washout in Daily DNT drilling jars (ser # 147-10019). Hole in bod 16.6' down f/ box. 22:15 00:00 1.75 3,784 3,784 PROD1 DRILL PULD T Lay down Daily DNT drilling jars (ser # 147-10019). Hole in body 16.6' down f/ box. Clean floor. PU/MU Daily jars (ser # 147-10005 . Rabbit 'ars to 1.62" ®. ~.~ ~ ®® aa... en_m~ .~..mm _____.. ._eee°a ~ .e~. _ . ~.de.. ,....~~m _ ~_.~.~ - ~~ ~{ --- -- - - - -- - Time Logs Date From To Dur ~ S. ua~r E. Depth Phase Code Subcode T __- _ _ 09/07/2006 00:00 00:30 0.50 3,784 3,940 PROD1 DRILL PULD T Lay down Daily accelerators (ser # 1447-71034}, PU Accelerators (ser # 1447-1003 w/ 77.54 hrs). Rabbit jars to 1.62" 00:30 01:00 0.50 3,940 3,940 PROD1 DRILL CIRC T Make up top drive, circ w/ # 1 mp @ 350 gpm (83 spm) w/ 2500 psi 31 flow, #2 mp 350 gpm (83 spm) w/ 2600 pis 31 % flow. Downlink, OK. MWD ood detection. 01:00 02:15 1.25 3,940 5,922 PROD1 DRILL TRIP T RIH w/ BHA #5 (number change after chan in out 'ars f/ 3940' to 5922'. 02:15 02:30 0.25 5,922 5,922 PROD1 DRILL CIRC T Fill pipe. Circ 82 spm w/ 2950 psi on Totco, 31 % flow. 02:30 03:30 1.00 5,922 7,600 PROD1 DRILL TRIP T RIH f/ 5922' to 7600'.Fill pipe. 03:30 05:30 2.00 7,600 7,646 PROD1 DRILL REAM T Time drill, 2 min per 1" f/ 7640' to 7644'., then 1 min per 1 ". f/ 7644' to 7646'. Toolface 145L, 80% deflection. 83 spm (350 gpm), w/ 3250 psi. Rotate 130 r m. PU wt 145k, SO wt 110k. 05:30 06:00 0.50 7,646 7,663 PROD1 DRILL REAM T Trying to sidetrack #2 f/ 7640', pumping 83 spm w/ 3250 psi, 140 rpm, 80% deflection. 85 spm (358 gpm) w/ 3300 psi. WOB 2k. Rotate 130 rpm w/ 5k for ue. ECD's 10.32 06:00 06:30 0.50 7,663 7,690 PROD1 DRILL REAM T Drilling f/ 7663' to 7690', survey, no sidetrack. 85 spm (358 gpm w/ 3300 si. Rotate 130 r m w/ 5k ft Ib for ue. 06:30 08:45 2.25 7,600 7,640 PROD1 DRILL REAM T Troughing and time drill f/ 7600' to 7640. 350 gpm, 3250 psi. 130 rpm w/ 5k ft Ib torque. Sidetrack #2 7600' 3737' TVD . 08:45 12:00 3.25 7,640 7,970 PROD1 DRILL DDRL T Drilling 6-3/4" production (sidetrack #2) A2 lateral f/ 7640' (3737' TVD) to 7970' (330') (3736' TVD) Bit hours= 2.45, Jar (#141-0005) hours= 2.45, Jar (#1471-0043) hours = 108.9, Accelerators (#1447-1033) = 79.99 hrs, ART= 2.45 hrs, WOB= 2-6k, 105-130 rpm, 345-350 gpm @ 3000-3100 psi on bottom and 2880-3010 psi off bottom. Torque = 4-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.13-10.28 ppg. Avg gas 80 units.P/U = 150k, S/O = 100k, Rot= 125k w< um off. ...~ .m~mm. ... ~ ~~~, ~ ~_. ~ ~ __ ~ ___. ~ ..~~m .w.-~~r ____~ ~ _ _. _ ~:- Time Logs _ __ Date From To Dur S D E. De th Phase Code Subcode T C 09/07/2006 12:00 16:30 4.50 7,970 8,401 PROD1 DRILL DDRL T ~ __ Drilling 6-3/4" production (sidetrack #2) A2 lateral f/ 7970' (3736' TVD) to 8401' (431') (3734' TVD) Bit hours= 6.01, Jar (#141-0005) hours= 6.01, Jar (#1471-0043) hours = 112.46 Accelerators (#1447-1033) = 83.55 hrs, ART= 3.56 hrs, WOB= 2-8k, 110-130 rpm, 350 gpm @ 3020-3120 psi on bottom and 3050-2940 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-6k ft-Ibs off bottom. ECD= 10.13-10.26 ppg. Avg gas 40 units.P/U = 155k, S/O = 95k, Rot= 125-120k w/ pump off. Started running Western Well Toois su er sliders 8162'. 16:30 18:00 1.50 8,401 8,508 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8401' (3734' TVD) to 8508' (107') (3736' TVD) Bit hours= 7.03, Jar (#141-0005) hours= 7.03, Jar (#1471-0043) hours = 113.48 Accelerators (#1447-1033) _ 84.57 hrs, ART= 1.02 hrs, WOB= 2-8k, 110-130 rpm, 350 gpm @ 3020-3120 psi on bottom and 3050-2940 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.26-10.36 ppg. Avg gas 33 units.P/U = 155k, S/O = 95k, Rot= 125-120k w/ um off. 18:00 00:00 6.00 8,508 9,025 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8508' (3736 TVD) to 9025(517') (3735' TVD) Bit hours= 11.42, Jar (#141-0005) hours= 11.42, Jar (#1471-0043) hours = 117.87 Accelerators (#1447-1033) = 88.96 hrs, ART= 4.39 hrs, WO6= 2-8k, 110-120 rpm, 350 gpm @ 3290-3450 psi on bottom and 3200-3450 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.26-10.95 ppg. Max gas 147 units.P/U = 155-165k, S/O = 95-100k, Rot= 125-120k w/ um off. r~ - ~ _Time Lois _ _ _ _ Date _ From To Dur S. E. De th Phase Code Subcode T c, 09/08/2006 00:00 06:00 6.00 9,025 9,430 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 9025' (3735 TVD) to 9430'(405') (3734.5' TVD) Bit hours= 16.15, Jar (#141-0005) hours= 16.15, Jar (#1471-0043) hours = 122.6 Accelerators (#1447-1033) = 93.69 hrs, ART= 4.73 hrs, WOB= 2-8k, 110 rpm, 350 gpm @ 3420-3450 psi on bottom and 3300-3400 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.92-11.01 ppg. Max gas 147 units.P/U = 165-170k, S/O = 95k, Rot= 120-122k w/ pump off. Pumped a 30 bbls hi vis sweep (225), while drillin 9401'- 9430'. 06:00 06:30 0.50 9,430 9,430 PROD1 DRILL CIRC P Finish circulating sweep out of hole. Slight increase in cuttings. Geologist in town suggested to continue drilling f/ 9430', down thru A2 sands. 06:30 10:30 4.00 9,430 9,846 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 9430' (3734.5 TVD) to 9846' (416') (3734.5' TVD) Bit hours= 19.28, Jar (#141-0005) hours= 19.28, Jar (#1471-0043) hours = 125.73 Accelerators (#1447-1033) = 96.82 hrs, ART= 3.13 hrs, WOB= 2-10k, 110-130 rpm, 345-350 gpm @ 3420-3980 psi on bottom and 3230-3840 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.01-11.68 ppg. Avg gas 30 units. P/U = 170-172k, S/O = 95k, Rot= 120k w/pump off. Pumped 40 bbls hi weight- hi vis sweep (10.8 ppg, 225 vis) while drilling 9750'-9846. 10:30 11:15 0.75 9,846 9,846 PROD1 DRILL CIRC P Finish circulating sweep out of hole. Slight increase in cuttings. Survey @ 9753'. Geologist suggested pulling back and sidetrack well a ain +/- 9200'. 11:15 12:15 1.00 9,846 9,191 PROD1 DRILL TRIP T POOH f/ 9846' to 9191' to sidetrack well. 12:15 13:00 0.75 9,191 9,210 PROD1 DRILL REAM T Trough f/ 9191' to 9210' for sidetrack #3. 13:00 13:15 0.25 9,210 9,219 PROD1 DRILL DDRL T Time drill f/ 9210' to 9219'. Rotate w/ 130 rpm, 80% deflection, TF 160L. Pum in 350 m. 13:15 13:30 0.25 9,219 9,210 PROD1 DRILL DDRL T Pull back, check sidetrack w/ ABI on geopilot. OK. Sidetracked well @ 9210'. ~e.__. _ ...._.___ __ _ e~ ~~.________ ~-_ .~._ __ ~.~_,~ _..,. ~.~..._.__ ~ _ __ _.~ -- --------- ----- - -- Time Logs Date From To Dur S. D E Depth Phase Code Subcode T 09!08/2006 13:30 18:00 4.50 9,210 9,730 PROD1 DRILL DDRL T Drilling 6-3/4" production (Sidedtrack #3) A2 lateral f/ 9210' (3734.5 TVD) to 9730' (539') (3736' TVD) Bit hours= 22.88, Jar (#141-0005) hours= 22.88, Jar (#1471-0043) hours = 129.33 Accelerators (#1447-1033) = 100.42 hrs, ART= 3.60 hrs, WOB= 2-6k, 110 rpm, 331-350 gpm @ 3310-3700 psi on bottom and 3240-3600 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.32-11.08 ppg. Avg gas 30 units. P/U = 165-170k, S/O = 100-95k, Rot= 120k w/ um off. 18:00 22:45 4.75 9,846 10,337 PROD1 DRILL DDRL P Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 9846' (3747' TVD) to 10337' (491') (3741' TVD) Bit hours= 26.83, Jar (#141-0005) hours= 26.83, Jar (#1471-0043) hours = 133.28 Accelerators (#1447-1033) = 104.37 hrs, ART= 3.23 hrs, WO6= 2-6k, 110 rpm, 350 gpm @ 3700-3870 psi on bottom and 3600-3780 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 6k ft-Ibs off bottom. ECD= 11.15-11.2 ppg. P/U = 170k, S/O = 90-85k, Rot= 122-120k w/ um off. 22:45 00:00 1.25 9,730 9,846 PROD1 DRILL DDRL T Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 9730' (3736' TVD) to 9846' (116') (3747' ND) Bit hours= 23.6, Jar (#141-0005) hours= 23.6, Jar {#1471-0043) hours = 130.05 Accelerators (#1447-1033) = 101.14 hrs, ART= 1.37 hrs, WOB= 2-6k, 110 rpm, 344 gpm @ 3700 psi on bottom and 3600 psi off bottom. Torque = 6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.08-11.15 ppg. P/U = 170k, S/O = 95-92k, Rot= 120-122k w/ um off. -_.. __.~.~~- ~~_~ _.~am r ~ ___ wm.m_ .-~_ ~~®~- -~n~~ ~ . m®em e-~ _. m ~e~ _ _ ~.m .~_- __~~. ~- ~ ~- ~ Time Logs __ Date From To Dur S. E. De th Phase Code Subcode T 09/09/2006 00:00 06:00 6.00 10,337 10,877 PROD1 DRILL DDRL P Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 10337' (3741' TVD) to 10877' (540') (3733' TVD) Bit hours= 31.29, Jar (#141-0005) hours= 31.29, Jar (#1471-0043) hours = 137.74 Accelerators (#1447-1033) = 108.83 hrs, ART= 4.46 hrs, WO6= 2-8k, 110 rpm, 350 gpm @ 34150-3980 psi on bottom and 4050-3910 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.23-11.56 ppg. P/U = 173-190k, S/O = 85-78k, Rot= 122-120k w/ pump off. Pumped weighted hi vis sweep (10.8 ppg, 225 vis) while drilling @ 10,499'-1-590'. Slight increase in cuttin s returns. 06:00 07:15 1.25 10,877 11,025 PROD1 DRILL DDRL P Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 10877' (3733' TVD) to 11025' (148') (3779' TVD) Bit hours= 32.22, Jar (#141-0005) hours= 32.22, Jar (#1471-0043) hours = 138.67 Accelerators (#1447-1033) = 109.76 hrs, ART= .93 hrs, WOB= 4-7k, 110 rpm, 350 gpm @ 3980 psi on bottom and 3910 psi off bottom. Torque = 7k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.23-11.56 ppg. Avg gas 35 units. P/U = 190k, S/O = 78k, Rot= 120k w/ um off. 07:15 08:30 1.25 11,025 10,035 PROD1 DRILL TRIP P POOH f/ 11025'to 10035'. 08:30 12:00 3.50 10,033 8,724 PROD1 DRILL REAM P Backream out of hole f/ 10035' to shoe @ 8724'. Pumping 350 gpm w/ 3570 psi. Rotate @ 130 rpm w/ 7k torque. ECD's 10.83 12:00 18:00 6.00 8,724 5,817 PROD1 DRILL REAM P Continue backreaming out of hole f/ 8724' to shoe @ 5920', then to 5817'. Pumping 350 gpm w/ 2800 psi. Rotate @ 130 rpm w/ 6k torque. ECD's 9.89 ppg. Pulling speed 40-45 ft/min. Tight s of 10035'. 18:00 19:30 1.50 5,817 5,817 PROD1 DRILL CIRC P MU top drive, pump 40 bbls hi vis his wt sweep (10.8ppg, 200 vis). Recip 5817' to 5720'. Rotate 100 rpm w/ 6k ft Ib torque, pump 350 gpm w/ 2850 psi. Pump surface to surface. PU wt 140k, SO wt 110k.then 2 BU. 19:30 21:00 1.50 5,817 5,815 PROD1 RIGMN SVRG P Service top drive and traveling equipment, crown. Inspect top drive. Re air broken tie wire on swivel. 21:00 23:00 2.00 5,815 10,035 PROD1 DRILL TRIP P Trip in hole f/ 5815' to 10035' (3768' TVD). Fill pipe every 20 stands purring 5.5 bpm w/ 1700 psi. Record PU and SO wt's eve 5 stands in o en hole. ae.® ®..e.~.._~r ____ ~ ~_.~_.ee e. ®.me-.~_ _ _~~....._~s~ ~-~e~~~ m ~_ ~~~ ~~.... ®- ~_ ~~.. _Time Logs _ ~ _ Date From To Dur S. D E. De th Phase Code Subcode T 09/09/2006 23:00 00:00 1.00 10,035 10,035 PROD1 DRILL CIRC P Establish circulation. Rotate @ 100 rpm w/ 6k ft Ib torque. Pumping 350 gpm w/ 3600 psi. Pump 40 bbls hi vis hi wt swee 10.8 , 200 vis . 09/10/2006 00:00 00:30 0.50 10,035 10,035 PROD1 DRILL CIRC P Establish circulation. Rotate @ 100 rpm w/ 6k ft Ib torque. Pumping 350 gpm w/ 3600 psi. Pump 40 bbls hi vis hi wt swee 10.8 , 200 vis . 00:30 00:45 0.25 10,035 10,035 PROD1 DRILL SFTY P PJSM on displacement f/ 8.8 ppg OBM to 8.7 ppg SFOBM. Continue circulating while conducting meeting. Total of 510 bbls um ed. 00:45 01:15 0.50 10,035 10,035 PROD1 DRILL CIRC P Displace 8.8ppg OBM w/ 8.7 ppg SFOBM. Pump 245 bbls, follow w/ 20 bbls dry job (10.8 ppg), then chase lines w/ 10 bbls. 01:15 01:45 0.50 10,035 10,035 PROD1 DRILL OWFF P Monitor well, OK. Blow down top drive. PJSM on POOH to run 4-1/2" liner. Drop 2-5/16" hollow rabbit w/ 120' wire on stand #65. 01:45 06:00 4.25 10,035 2,147 PROD1 DRILL TRIP P POOH f/ 10035' (3668' TVD) to 2147'. PU and SO wt's @ 2147' : 107k up, 107k down. 06:00 08:15 2.25 2,147 92 PROD1 DRILL TRIP P Continue trip out w/ BHA #5 f/ 2147' to 92', to run 4-1/2" A2 liner. 08:15 09:00 0.75 92 92 PROD1 DRILL OTHR P Download Sperry Sun MWD tools. 09:00 10:15 1.25 92 0 PROD1 DRILL PULD P UD BHA #5. 10:15 11:00 0.75 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. RU to run 4-1/2" 11.6 ppg, L-80, BTC slotted and blank liner. 11:00 11:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" 11.6 ppf, L-80 BTC slotted/blank liner. 11:15 16:00 4.75 0 4,857 COMPZ CASIN( RNCS P RIH w/ 4-1/2" slotted liner per detail. Run 3-1/2" 9.3 ppf L-80 EUE 8rd (orange peeled end), x-o, x-o, 4-1/2" Easy Well Solutions Swell Packer, then 4-1/2" 11.6 ppf L-80 BTC slots and blanks. Run 31 slots (1309.01') and 83 blanks (3472.64'), 4-1/2" pupjt, x-o bushing, 190-47 casing seal bore extension to 4857 16:00 16:30 0.50 4,857 4,857 COMPZ CASIN( RNCS P PU/MU Baker "HRD" ZXP liner top packer assembly. GBR casing tongs locked up and damaged Flex Lock liner hanger, while trying to torque to 7900 ft lbs. 16:30 17:30 1.00 4,857 4,857 COMPZ CASIN( OTHR T Remove GBR power tongs f/ liner han er assembl . 17:30 18:00 0.50 4,857 4,857 COMPZ CASIN( OTHR T UD Baker finer hanger assembly to send to Deadhorse to have Flex-Lockliner han er chan ed out. I Time Los _ _ _ _ _ _ Date From To Dur S: D E. De th Phase Code Subcode T L 09/10/2006 18:00 21:15 3.25 4,857 4,857 COMPZ CASIN( WOEQ T Waiting on Baker hanger. Hanger sent to Baker Machine shop to remove Flex lock hanger and apply another. Clear and clean rig floor. RU GBR backu set of ton s. 21:15 21:30 0.25 4,857 4,857 COMPZ CASIN( OTHR T Load baker liner hanger assembly into i e shed. 21:30 22:00 0.50 4,890 4,890 COMPZ CASIN( RNCS T PU/ MU Baker hanger assembly to 7000 ft Ib torque. Check brass screws. RIH to 4890'. 22:00 22:45 0.75 4,890 4,890 COMPZ CASIN( OTHR P Mix gel (PAL Mix) to pour in liner top tie back extension. Allow el to set u . 22:45 23:00 0.25 4,890 4,900 COMPZ CASIN( OTHR P RIH w/ Baker liner hanger assembly to 4900'. Chan a elevators f/ 3-1 /2" to 4". 23:00 00:00 1.00 4,900 5,920 COMPZ CASIN( RUNL P RIH w/ 4-1/2" slotted/blank liner f/ 4900' to 5900'. Run on 4" dp w/super sliders. Run 11 stands till midnight. Record PUwt 128k, SO wt 105k, Roate wt 115k. Roate @ 25 rpm w/ 3-4k ft Ib torque. Circ 3 bpm w/ 250 psi w/ 18% flow. 09/11/2006 00:00 04:30 4.50 5,920 10,058 COMPZ CASIN< RUNL P RIH w/ 4-1/2" slotted/blank liner on 4" drill pipe f/ 5900' to 10058'. Run on 4" dp w/ super sliders. Run 36 stands total, then 4 stands 4" HWDP, then 15 stands hybrids [(2) 5" DC's w/ (1) 4" HWDP on top], then PU single HWDP. Record PU and SO wt's every 5 stands in open hole. Rabbit to 2.33" f/ 20th stand of super sliders to stand 36, then all 4 HWDP, 15 hybrids and single HWDP. Break circ every 20 stands. Circ @ 5900' 3 bpm w/ 250 psi. PU wt 128k, SO wt 105k. Rotate @ 20 rpm w/ 3-4k ft Ib torque. Rotating weight 115k. Circ @ 7700' 3 bpm w/ 350 si. PU wt 150k, SO wt 100k. 04:30 05:00 0.50 10,058 10,040 COMPZ CASIN( OTHR P Work liner f/ 10058 to 10030'. Record PU and SO wt's. Beginning PU wt 215k, SO wt 105k. After working twice the PU wt was 205k, SO wt 112k. Drop 1-3/4" ball and set pipe on depth w/ top of liner @ 5149.6' and bottom of ~°' 3-1/2" shoe joint @ 10040.39' while circulating ball down @ 3 bpm w/ 500 Sf. 05:00 05:30 0.50 10,040 5,150 COMPZ CASIN( OTHR P Pressure up to 1600 psi, set down, Pick back up to mark, pressure to 2500 psi, slack off to 70k (top drive wt), liner set. Pressure to 3900 psi and release liner. PU 5', break off single. PU wt 180-185k. SO wt 142k. 05:30 05:45 0.25 5,150 5,150 COMPZ CASINC DHEQ P Pressure test packer and annulus to 1000 si f/ 5 min. Chart test. 05:45 06:00 0.25 5,150 5,150 COMPZ CASIN( OTHR P Pick up, slack off to tag top of liner w/ do s. _~m..e, ®~~ _~.. m..~~ ~.~ __ ~ ~~ Time Logs Date From To Dur S. D E De th Phase Code Subcode T _ 09/11/2006 06:00 06:45 0.75 5,150 5,039 COMPZ CASIN( RUNL P Pull and set back a stand wet.to 5039'. 06:45 07:30 0.75 5,039 5,039 COMPZ CASIN( CIRC P Circulate bottoms up @ 5 bpm w/ 800 si. Pum ed 150 bbls. 07:30 08:00 0.50 5,039 4,946 COMPZ CASIN( RUNL P Pull and set back a stand wet.to 4946'. 08:00 08:30 0.50 4,946 4,946 COMPZ CASIN( CIRC P Pipe was pulling wet. Pumped 30 bbls dry job. Blow down top drive and kill line. 08:30 11:00 2.50 4,946 0 COMPZ CASIN( RUNL P Continue POOH w/ Baker liner running tool. Cleaning and inspecting 4" Western Well Toolssuper sliders on wa out. 11:00 11:45 0.75 0 0 COMPZ CASIN( OTHR P Break and lay down Baker liner runnin tool. 11:45 12:30 0.75 0 0 COMPZ CASIN( OTHR P Clear and clean rig floor after POOH w/ A2 liner runnin tools. 12:30 13:15 0.75 0 0 COMPZ EVALV~ SFTY P PJSM w/ Schlumberger wireline on RU and running USIT. Safety meeting w/ both ri crews. 13:15 14:30 1.25 0 0 COMPZ EVALVI~ RURD P Rig up Schlumberger wireline. MU toolstrin .. 14:30 15:45 1.25 0 0 COMPZ EVAL1/1~ OTHR T RIH w/ USIT and tractor to 200'. Trouble shoot problem w/tools string. POOH change sub. RIH to 200'. Same roblem. POOH, Chan a out SONDE. 15:45 17:15 1.50 0 5,120 COMPZ EVALVI~ ELOG P RIH w/ Schlumberger USIT and Schlumberger tractor. RIH to 4750', tractor f/ 4750' to 5120'. 17:15 18:45 1.50 5,120 0 COMPZ EVALVI~ ELOG T Trouble w/USIT toolstring. Touble shoot problem. POOH to continue troubleshooting toolstring. Found bad telemet cartid a Brains . 18:45 19:30 0.75 0 5,120 COMPZ EVALV~ ELOG T RIH w/ Schlumberger USIT and tractor to 4850', tractor f/ 4850' to 5120'. 19:30 21:00 1.50 5,120 0 COMPZ EVALV~ ELOG P Begin logging up. Logged to 2700'. POOH. Identified top of cement @ 2885'. Note: 10-3/4" shoe @ 2642.83'. TOC is 242.17' below 10-3/4" shoe. Well was flushed and freeze protected w/ 80 bbls diesel on 9/2/2006. 21:00 22:00 1.00 0 0 COMPZ EVALVI RURD P Rig down Schlumberger wireline. 22:00 22:30 0.50 0 0 COMPZ WELCT OTHR P Pulf Vetco gray wear bushing. 22:30 00:00 1.50 0 0 COMPZ WELCT BOPE P Set Vetco Gray test plug. PJSM. RU to test BOPE. 09/12/2006 00:00 06:30 6.50 0 0 COMPZ WELCT BOPE P Test BOPE (2 week test). Test witnessed by AOGCC inspector John Spaulding. Test all to 250 low f/ 5 min, then to 3000 si hi f/ 5 min. Chart test. 06:30 08:00 1.50 0 0 COMPZ WELCT OTHR P Rig down BOPE testing equipment. Pull test plug. Install Vetco Gray wear bushing.Blow down kill line, choke line, choke manifold and to drive. ~~ Time Logs Date From To Dur S. D .Rf E. D~th Phase Code Subcode T ~ 09/12/2006 08:00 09:00 1.00 0 0 PROD2 FISH SFTY P PJSM on picking up BHA #6 (Whipstock f/ "B" lateral). Pull all tools to ri floor. 09:00 09:30 0.50 0 0 PROD2 FISH PULD P Breakout & lay down Smart Stabilizer & PWD assembl . 09:30 11:00 1.50 0 200 PROD2 FISH PULD P PU/MU BHA #6 (Whipstock & mills f/ 'B" lateral). Make up Baker Seal assembly w/ No-Go (1.92'), 4 3/4" Unloader Sub (5.18'), 2 -joints of 3 1/2" DP (62.30'), 3 1/2" Flex Joint (6.50'), Double Pin Crossover (2.28'), 7 5/8" Bottom Trip Anchor (3.23'), 3 1/2" Shear Disconnect (1.69'), 4 3/4" Drain Sub (1.49'), Debris Sub with Cup (2.0'), 7 5/8" Whipstock Slide (14.45'), 6.156" Starting Mill (1.08'), 6.313" Lower Mill (5.57'), 6 3/4" Upper watermelon mill (5.83'), 1 -joint 3 1/2" HWDP (29.80'), 4 3/4" Float sub 2.33' . 11:00 12:00 1.00 200 250 PROD2 FISH PULD P Make up 4 3/4" MWD assembly (46.02'). Orient MWD to whipstock face. Plug in and download MWD assembl . 12:00 13:30 1.50 250 250 PROD2 FISH PULD P Continue download & orient MWD to whipstock face. Observe bad Float in FLoat sub, Chan a out same. 13:30 14:00 0.50 250 485 PROD2 FISH PULD P Complete make up BHA with 4 3/4" Bumper Jar (7.73'), Crossover Sub (2.99'), and 3 -stands of Hybrid Drill Collars (278.43'). Total BHA = 485.03'. Total BHA after setting whipstock = 379.78'. 14:00 14:30 0.50 485 485 PROD2 FISH PULD P Make Top Drive connection .Rig up to perform Pulse test on MWD assembly. Pumps @ 300 GPM - 890 PSI. Good test. 14:30 18:00 3.50 485 3,477 PROD2 FISH TRIP P Trip in hole with BHA #6 at 3 -minutes / stand as per Baker Rep, and Co. Rep from 485' - 3477'. Fill Drill String every 25 stands. Crew Chan e. ,.aae~ ~.~ __ .. ~ ~ e ~ ~ ®e....... ..~~ ~ - .. m~s ~__._ _ . ~.__. ~ - ~ ..._..m ~ ~ e e_ ®®~. ~ ..~m ~. mma- ~ .. e.....e ~~_ .~-_ ~ ~ ~... .®~__.. _.....~.-,®~ ~._~„ ~ ..~.«_ m~~ Time Logs -_- -- -- -- Date From To Dur _ S E. De th Phase Code Subcode T _ 09/12/2006 18:00 21:30 3.50 3,477 5,149 PROD2 FISH TRIP _ P Continue trip in hole with BHA #6 at 3 - minutes /stand as per Baker Rep, and Co. Rep from 3477' - 5149'. Fill Drill String every 25 stands. Perform MAd PAss survey as per Geo from 4320' - 4380' MD, with pumps @ 295 GPM's - 1675 PSI. Pick up 1 single of drill pipe for setting whipstock. Make TD connection and orient whipstock face @ 14 Deg Left of High Side as per DD, and Co. Rep. Pumps @ 300 GPM's - 1680 PSI. UP WT = 170K, SO WT = 139K. Locate top of A lateral liner @ 5149' MD, observe seals going into liner top & set down 20K to observe BTA set. Pick up to 10K over ensuring BTA set. Slack off to 35K below downweight and observe bolt shear. Pick up to neutral. Slowly rotate drill string observing free rotation with 60 21:30 00:00 2.50 5,047 5,058 PROD2 FISH MILL P Mill window in the 7 5/8" casing from 5047' - 5058' (11') with 290 GPMs - 1900 PSI. WOB = 2-3K, 80 RPM's, ` ~ ._~~ with 3-6K torque. Observe good kick off with mills, no high torque or hanging u issues. 09/13/2006 00:00 01:00 1.00 5,058 5,070 PROD2 FISH MILL P Continue Mill window from 5047' - 5059' (12'), and then open hole from 5059' - 5070' as per Baker rep. Pumps @300 GPM's - 1900 PSI. 80 RPM's with 4-5K torque. Work window observin clean hole conditions. 01:00 02:00 1.00 5,070 5,070 PROD2 FISH CIRC P Pump 35 BBLs of Hi Visc sweep @ 300 GPM's - 1900 PSI. Observe good Iron returns in swee . 02:00 02:30 0.50 5,070 5,070 PROD2 FISH CIRC P Monitor well -static. Work mills through window area with no rotation or pump as per Baker rep, Good hole conditions. Pum d "ob. 02:30 06:00 3.50 5,070 0 PROD2 FISH TRIP P POOH with BHA #6, Whipstock mills & MWD assembly from 5070' to surface. Crew Chan e 06:00 07:00 1.00 0 0 PROD2 FISH PULD P Continue POOH breakout & lay down MWD and milling assembly. Lay down 6.156" Starting Mill (1.08'), 6.313" Lower Mill (5.57'), 6 3/4" Upper watermelon mill (5.83'), 1 -joint 3 1/2" HWDP (29.80'), 4 3/4" Float sub (2.33'), and 4 3/4" MWD assembly (46.02'). Inspect and gauge upper watermelon mill to full au eat 6 3/4". 07:00 07:30 0.50 0 0 PROD2 FISH PULD P Clean & clear rig floor of all milling tools and OBM. ,. _.______.__ __.__... ._ ..._...~.__.___.. ..._...r~_..__.._. Time Los ___ Date _ From To Dur S.. E. De _th Phase Code Subcode T _ T 09/13/2006 07:30 08:30 1.00 0 0 PROD2 DRILL OTHR P Make up Stack washing tool and RIH to flush stack of all metal cuttings from milling. Function rams, HCR's, and manual valves while flushing. Blow down all lines, and To Drive. 08:30 09:00 0.50 0 0 PROD2 DRILL OTHR P Breakout & lay down Stack washing tool. prepare rig floor for MU BHA #7. Hold PJSM with crew, DD &MWD reps. Discuss safety issues and procedure for making up 6 3/4" driling assembl ,BHA #7. 09:00 12:00 3.00 0 3,496 PROD2 DRILL PULD P Make up 6 3/4" Smith bit MDT52 9.84') with 6 x 13's jets for a TFA of .778 sq. in. on a 5" SperryDrill 6/7-6.0 stg w/ ABI motor (32.02'), 4 3/4" Non MAg Float sub (2.33'), 4.870" Welded Blade Stabilizer (5.22'), 4 3/4" MWD terminating sub (1.85'}, 4 3/4" Gamma/Res (24.52'), MWD Directional (8.56'), 4 3/4" PWD (10.82'), 4 3/4" TM HOC (11.10'), 3 -Non MAg Flex Drill Collars (93.28'), Crossover Sub (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailry Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), 48 jnts of 4" XT39 DP (1498.26'), Crossover sub (2.97'), Agitator (8.75'), Shock Sub (8.30'), Crossover sub (3.00'), 48 jnts of 4" XT39 DP (1500.26'), Dailey DNT Mechanical jars (32.24'), 2 jnts of 4" XT39 DP 962.32'), Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Total BHA #7 = 3496.58'. perform Shallow pulse test on MWD with pumps @ 245 GPMs- 1100 PSI. Good test. 12:00 15:15 3.25 3,496 4,960 PROD2 DRILL TRIP P Trip in hole with 4" DP from 3496' - 4960'. 15:15 15:45 0.50 4,960 4,960 PROD2 DRILL TRIP P Fill drill string with mud, check pump pressures and MWD assembly. Held "Man down drill". 15:45 16:00 0.25 4,960 4,960 PROD2 RIGMN SFTY P Held PJSM with rig crew. Discuss Safety issues and procedure for sli in and cuttin drillin line. 16:00 17:30 1.50 4,960 4,960 PROD2 RIGMN SVRG P Slip & cut 110' of drilling line. Inspect and adjust brakes on draw works. Service Top drive, Blocks and crown section. Inspect shot pin asembly on TD. ~~ee s .~ ..®._ _~ ~ _ m~°e_ ®zs~__ ~.______~ '~_ ~ 1 ~~ C Time Logs _ _ Date From To Dur S. D E De th Phase Ccde Subcode T~ - 09/13/2006 17:30 18:00 0.50 4,960 5,062 PROD2 DRILL TRIP P -- -- - Continue trip in hole with 4" DP to 5000' MD. Fill drill string Obtain SPR's, and orient tool face on drill string to 15 degrees left of high side for passing through window area @ 5047' - 5059' MD. Observe no issues going through window and continue TIH to tag @ 5062' MD. Wash down to 5070'. Crew Chan e 18:00 00:00 6.00 5,062 5,279 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5070' - 5279' MD (209'). TVD = 3606'. Pumps @ 300 GPMs - 3150 PSI. RPMs = 70-80, WOB = 2-10K, Torque on = 5K, Torque Off btm = 3K, UP WT = 138K, SO WT = 110K, ROT WT = 125K,. ADT = 3.16 HRS, AST = 2.09 HRS, ART = 1.07 HRS. Total Bit HRS = 3.16 HRS. Total Jar HRS #14710043 = 141.83 HRS. Total Jar HRS # 14710005 = 35.38 HRS. ACC HRS = 112.92. MAx gas observed = 134 units, ECD = 9.48 PPG. Observed drilling Concretions @ 5077'-5079', 5101'-5106', 5122'-5129', 5146'-5150', 5160'-5168', 5182'-5185', 5200'-5204', for a total of 33'. Survey @ 5207.76 MD, INC = 93.83 DEG, AZ = 179.27 DEG, 3610.26 TVD. Mud WT = 8.85 PPG Visc = 62, YP = 18, PV = 16. Gels = 16/26/34 09/14/2006 00:00 06:00 6.00 5,279 5,396 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5279' - 5396' MD (117'). TVD = 3599'. Pumps @ 300 GPMs - 3320 PSI. RPMs = 70-80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 135K, SO WT = 110K, ROT WT = 125K,. ADT = 7.41 HRS, AST = 4.30 HRS, ART = 3.11 HRS. Total Bit HRS = 7.41 HRS. Total Jar HRS #14710043 = 146.08 HRS. Total Jar HRS # 14710005 = 39.63 HRS. ACC HRS = 117.08. Max gas observed = 98 units, ECD = 9.55 PPG. Observed drilling Concretions @ 5286'-5298, 5300'-5313',5337'-5346',5385'-5395' for a total of 44'. Survey @ 5394.41 MD, INC = 87.96 DEG, AZ = 182.35 DEG, 3602.10 TVD. Mud WT = 8.8 PPG Visc = 61, YP = 18, PV = 16. Gels = 17/25. Crew Chan e r'a: Time Logs _ _ ~ Date From To Dur S. D E. De th Phase Code Subcode T 09/14/2006 06:00 12:00 6.00 5,396 5,748 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5396' - 5748' MD (352'). TVD = 3599'. Pumps @ 300 GPMs - 3350 PSI. RPMs = 70-90, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 140K, SO WT = 112K, ROT WT = 125K,. ADT = 7.41 HRS, AST = 4.30 HRS, ART = 3.11 HRS. Total Bit HRS = 10.90 HRS. Total Jar HRS #14710043 = 149.57 HRS. Total Jar HRS # 14710005 = 43.12 HRS. ACC HRS = 120.66. Max gas observed = 29 units, ECD = 9.80 PPG. Observed drilling Concretions @ 5435'-5441', 5465'-5473', 5478'-5490',559 9'-5604',5650'-5657', for a total of 38'. Survey @ 5676.75 MD, INC = 90.44 DEG, AZ = 183.07 DEG, 3599.35 TVD. Mud WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16/24. Obtain Slow pump rates @ 5730' MD, TVD - 3603'. #1 pump @ 20 SPM - 470 PSI, 30 SPM - 740 PSI. #2 pump @ 20 SPM - 430 PSI, 30 SPM - 730 PSI. 12:00 18:00 6.00 5,748 5,987 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5748' - 5987' MD (239'). TVD = 3591'. Pumps @ 300 GPMs - 3450 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 145K, SO WT = 110K, ROT WT = 124K,. ADT = 3.60 HRS, AST = 2.42 HRS, ART = 1.18 HRS. Total Bit HRS = 14.50 HRS. Total Jar HRS #14710043 = 153.17 HRS. Total Jar HRS # 14710005 = 46.72 HRS. ACC HRS = 124.26. Max gas observed = 64 units, ECD = 9.72 PPG. Observed drilling Concretions @ 5815'-5833', 5842'-5858',5878'-5881',590 5'-5914',5947'-5950',5954'-5963', for a total of 58'. Survey @ 5955.41' MD, INC = 88.78 DEG, AZ = 182.51 DEG, 3592.07 TVD. Mud WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16/24. Obtain Slow pump rates @ 6020' MD, TVD - 3592'. #1 pump @ 20 SPM - 490 PSI, 30 SPM - 840 PSI. #2 pump @ 20 SPM - 480 PSI, 30 SPM - 750 PSI. Crew Chan e ~ _..~ ..e.® ~..®~~.__.w._a®e~ m.~.-. Ha.m..m ~®- ~ ~_._..e ...~~~~~~ ._ ... ~ ....__ ~~~..._ ....-.. d.w~ , ~ ...~ ~ ~_ ~._._. ~e.. .-__~___ _. n.~e_ ~ ..._ .___ __ ~ ..~,. ~ .-_._..._._ _~ ~ .____._._ ~._._ _.,. ,,.~. _ ~~ ~~__s Time Logs _ _ __ Date From To Dur S D E. De th Phase Code Subcode T 09/14/2006 18:00 00:00 6.00 5,987 6,308 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5987'- 6308' MD (321'). TVD = 3590'. Pumps @ 300 GPMs - 3400 PS1. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 145K, SO WT = 110K, ROT WT = 122K,. ADT = 3.14 HRS, AST = .74 HRS, ART = 2.40 HRS. Total Bit HRS = 17.64 HRS. Total Jar HRS #14710043 = 156.31 HRS. Total Jar HRS # 14710005 = 49.86 HRS. ACC HRS = 127.40. Max gas observed = 161 units, ECD = 9.8 PPG. Observed drilling Concretions @ 6000'-6005', 6047'-6056',6073'-6086' ,611 7'-6127',6133'-6135',6145'-6150', for a total of 44'. Surrey @ 6190.88' MD, INC = 90.31 DEG, AZ = 180.88 DEG, 3593.34 TVD. Mud WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16/24. 09/15/2006 00:00 06:00 6.00 6,308 6,869 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 6308' - 6869' MD (561'). TVD = 3591'. Pumps @ 300 GPMs - 3500 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 142K, SO WT = 105K, ROT WT = 125K,. ADT = 3.35 HRS, AST = .77 HRS, ART = 2.58 HRS. Total Bit HRS = 20.99 HRS. Total Jar HRS #14710043 = 159.66 HRS. Total Jar HRS # 14710005 = 53.21 HRS. ACC HRS = 130.75. Max gas observed = 188 units, ECD = 10.0 PPG. Observed drilling Concretions @ 6310'-6312',6802'-6808', for a total of 8'. Survey @ 6843.65' MD, INC = 88.57 DEG, AZ = 180.07 DEG, 3588.26 TVD. Mud WT = 8.9 PPG Visc = 75, YP = 19, PV = 17. Gels = 20/28. Obtain Slow pump rates @ 6869' MD, TVD - 3590'. #1 pump @ 20 SPM - 540 PSI, 30 SPM - 810 PSI. #2 pump @ 20 SPM - 550 PSI, 30 SPM - 820 PSI. Crew Chan e ~ a a ~ t._e~ ~~...~ - . ~ _.~.. -~.®e .. ____ ~_ memma.~..__ __ .__ e.~. ...~_ ®a ~ ___._ ..... _~ ~__ ~ ~ ~ _ ~. .®._em ~ ~ ~'~ _______, ~ ~ .~. ~.. , E ~ Time L~ ~ ~ ~~ ~- Date From To Dur S. D E. De th Phase _ Code Subcode T _ 09/15/2006 06:00 12:00 6.00 6,869 7,151 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 6869' - 7151' MD (282'). TVD = 3581'. Pumps @ 300 GPMs - 3450 PSI. RPMs = 80, WOB = 5-8K, Torque on = 5K, Torque Off btm = 4K, UP WT = 150K, SO WT = 106K, ROT WT = 126K,. ADT = 3.21 HRS, AST = .99 HRS, ART = 2.22 HRS. Total Bit HRS = 24.20 HRS. Total Jar HRS #14710043 = 162.87 HRS. Total Jar HRS # 14710005 = 56.42 HRS. ACC HRS = 133.96. Max gas observed = 148 units, ECD = 9.75 PPG. Observed drilling Concretions @ 7115'-7127', for a total of 12'. Survey @ 7126.83' MD, INC = 92.96 DEG, AZ = 179.78 DEG, 3583.46 TVD. Mud WT = 8.9 PPG Visc = 75, YP = 19, PV = 17. Gels = 20/28. 12:00 18:00 6.00 7,151 7,402 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 7151'-7402' MD (251'). TVD = 3584'. Pumps @ 300 GPMs - 3510 PSI. RPMs = 80, WOB = 5-8K, Torque on = 5K, Torque Off btm = 5K, UP WT = 151 K, SO WT = 107K, ROT WT = 128K,. ADT = 3.35 HRS, AST = .90 HRS, ART = 2.58 HRS. Total Bit HRS = 27.68 HRS. Total Jar HRS #14710043 = 166.35 HRS. Total Jar HRS # 14710005 = 59.90 HRS. ACC HRS = 137.44. Max gas observed = 152 units, ECD = 9.98 PPG. Observed drilling Concretions @ 7199'-7214', 7245'-7247', 7266'-7273' , 737 6'-7384',7394'-7415', for a total of 43'. Surrey @ 7361.02' MD, INC = 88.95 DEG, AZ = 180.23 DEG, 3583.12 TVD. Mud WT = 8.75 PPG Visc = 63, YP = 21, PV = 17. Gels = 16/27. Obtain Slow pump rates @ 7432' MD, TVD - 3588'. #1 pump @ 20 SPM - 590 PSI, 30 SPM - 870 PSI. #2 pump @ 20 SPM - 600 PSI, 30 SPM - 870 PSI. Crew Chan e ~~~_~n s :Time Logs - -- _ _ Date From To Dur S. E. De th Phase Code Subcode T _ 09!15/2006 18:00 00:00 6.00 7,402 7,714 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 7402'-7714' MD (312'). TVD = 3586'. Pumps @ 300 GPMs - 3620 PSI. RPMs = 80, WOB = 2-8K, Torque on = 5K, Torque Off btm = 5K, UP WT = 150K, SO WT = 105K, ROT WT = 122K,. ADT = 2.99 HRS, AST = .29 HRS, ART = 2.70 HRS. Total Bit HRS = 30.67 HRS. Total Jar HRS #14710043 = 169.34 HRS. Total Jar HRS # 14710005 = 62.89 HRS. ACC HRS = 140.43. Max gas observed = 197 units, ECD = 10.01 PPG. Observed drilling Concretions @ 7457'-7466',7487'-7495',7563'-7576', for a total of 30'. Survey @ 7643.08' MD, INC = 90.00 DEG, AZ = 177.14 DEG, 3587.11 TVD. Mud WT = 8.75 PPG Visc = 69, YP = 21, PV = 19. Gels = 26/33. Obtain Slow pump rates @ 7432' MD, TVD - 3588'. #1 pump @ 20 SPM - 590 PSI, 30 SPM - 870 PSI. #2 pump @ 20 SPM - 600 PSI, 30 SPM - 870 PSI. 09/16/2006 00:00 02:45 2.75 7,714 7,714 PROD2 RIGMN RGRP NP Pull 1 stand. Monitor wel -static. Install Safety Valve in drill string. Work drill string periodically while change out Saver Sub on Top Drive. Observed no well control issues while C/O saver sub. 02:45 06:00 3.25 7,714 8,016 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole ~ the B Lateral from 7714' - 8016' MD (302'). TVD = 3583'. Pumps @ 300 GPMs - 3670 PSI. RPMs = 80, WOB = 2-6K, Torque on = 6K, Torque Off btm = 5K, UP WT = 150K, SO WT = 100K, ROT WT = 122K,. ADT = 1.60 HRS, AST = .33 HRS, ART = 1.27 HRS. Total Bit HRS = 32.27 HRS. Total Jar HRS #14710043 = 170.94 HRS. Total Jar HRS # 14710005 = 64.89 HRS. ACC HRS = 141.54. Max gas observed = 158 units, ECD = 10.28 PPG. Observed drilling Concretions @ 7849'-7853', for a total of 4'. Survey @ 8017.86' MD, INC = 91.73 DEG, AZ = 179.80 DEG, 3582.80 TVD. Mud WT = 8.75 PPG Visc = 69, YP = 21, PV = 19. Gels = 26/33. Obtain Slow pump rates @ 8091' MD, TVD - 3588'. #1 pump @ 20 SPM - 620 PSI, 30 SPM - 900 PSI. #2 pump @ 20 SPM - 630 PSI, 30 SPM - 920 PSI. Crew Chan e er~®Q ~....~ a__ _ ~.e®~ _ ~ ~~ _ .m .. ~ .~... ~..~ __~~ w~_~ ~. ~~ ww v. s... . ~~_ ~ ~.~ ~.. _r._~__ e.® ~_ ,, ~~ Time Los _ Date From To Dur S. E. De th Phase Code Subcode T _ ~ 09/16/2006 06:00 12:00 6.00 8,016 8,321 PROD2 DRILL DDRL P _ _ Directional Drili 6 3/4' hole in the B Lateral from 8016' - 8321' MD (305'). TVD = 3579'. Pumps @ 300 GPMs - 3700 PSI. RPMs = 90, WOB = 5-8K, Torque on = 6K, Torque Off btm = 5K, UP WT = 150K, SO WT = 105K, ROT WT = 123K,. ADT = 3.84 HRS, AST = .98 HRS, ART = 2.86 HRS. Total Bit HRS = 36.11 HRS. Total Jar HRS #14710043 = 174.78 HRS. Total Jar HRS # 14710005 = 68.33 HRS. ACC HRS = 145.87. Max gas observed = 145 units, ECD = 10.15 PPG. Observed drilling Concretions @ 8045'-8048', 8082'-8086', 8092'-8118',819 0'-8210',8300'-8303', for a total of 56'. Survey @ 8297.15' MD, INC = 91.42 DEG, AZ = 181.86 DEG, 3578.31 TVD. Mud WT = 8.8 PPG Visc = 62, YP = 20, PV = 16. Gels = 25/26. 12:00 18:00 6.00 8,321 8,630 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 8321'-8630' MD (309'). TVD = 3569'. Pumps @ 322 GPMs - 4150 PSI. RPMs = 80, WOB = 8-10K, Torque on = 7K, Torque Off btm = 6K, UP WT = 160K, SO WT = 100K, ROT WT = 125K,. ADT = 3.58 HRS, AST = .84 HRS, ART = 2.74 HRS. Total Bit HRS = 39.69 HRS. Total Jar HRS #14710043 = 178.36 HRS. Total Jar HRS # 14710005 = 71.91 HRS. ACC HRS = 149.45. Max gas observed = 217 units, ECD = 10.12 PPG. Observed drilling Concretions @ 8322'-8326', 8341'-8343',8348'-8350',852 5'-8534' , 8535'-8543' , 8547'-8550' , 8605'-8 609', for a total of 32'. Survey @ 8628.68' MD, INC = 88.53 DEG, AZ = 180.78 DEG, 3574.41 TVD. Mud WT = 8.8 PPG Visc = 62, YP = 20, PV = 16. Gels = 25/26. Obtain Slow pump rates @ 8653' MD, TVD - 3574'. #1 pump @ 20 SPM - 580 PSI, 30 SPM - 920 PSI. #2 pump @ 20 SPM - 580 PSI, 30 SPM - 850 PSI. Crew Chan e Time Logs - -- - - - - - _ Date From To Dur S. C i E. Depth Phase Code Subcode T I 09/16/2006 18:00 00:00 6.00 8,630 8,933 PROD2 DRILL _ DDRL P _ Directional Drill 6 3/4' hole in the B Lateral from 8630'-8933' MD (303'). TVD = 3960'. Pumps @ 310 GPMs - 3960 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 158K, SO WT = 98K, ROT WT = 120K,. ADT = 4.17 HRS, AST = .53 HRS, ART = 3.64 HRS. Total Bit HRS = 43.86 HRS. Total Jar HRS #14710043 = 182.53 HRS. Total Jar HRS # 14710005 = 76.08 HRS. ACC HRS = 153.62. Max gas observed = 250 units, ECD = 10.30 PPG. Observed drilling Concretions @ 8665'-8670' , 8672'-8689' , 8699'-8704' , 870 7'-8719',8729'-8737', for a total of 47'. Survey @ 8768.72' MD, INC = 88.84 DEG, AZ = 180.97 DEG, 3578.98 TVD. Mud WT = 8.8 PPG Visc = 63, YP = 19, PV = 17. Gels = 30/33. 09/17!2006 00:00 06:00 6.00 8,933 9,170 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 8933'-9170' MD (237'). TVD = 3592'. Pumps @ 310 GPMs - 3720 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 160K, SO WT = 98K, ROT WT = 122K,. ADT = 3.69 HRS, AST = .58 HRS, ART = 3.11 HRS. Total Bit HRS = 47.55 HRS. Total Jar HRS #14710043 = 186.22 HRS. Total Jar HRS # 14710005 = 79.77 HRS. ACC HRS = 157.31. Max gas observed = 159 units, ECD = 10.40 PPG. Observed drilling Concretions @ 8998'-9004' , 9055'-9059' , 9060'-9070' , 913 3'-9147',9150'-9160'„ for a total of 44'. Survey @ 9140.86' MD, INC = 90.64 DEG, AZ = 174.87 DEG, 3591.18 TVD. Mud WT = 8.75 PPG Visc = 63, YP = 19, PV = 17. Gels = 25/30. Crew Chan e ~R ~ ®.a~ ~... e .. ~e.~- __ ._.-.~~ ......~ ea ~ ~ ~~~ ~_ ~ ~. ~~ ...~_ ._..,.-.... Time Logs ~ Date From To Dur S. _ E De th Phase Code _ Subcode T _ 09/17/2006 06:00 12:00 6.00 9,170 9,472 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9170' -9472' MD (302'). TVD = 3599'. Pumps @ 315 GPMs - 4000 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 170K, SO WT = 109K, ROT WT = 122K,. ADT = 3.71 HRS, AST = .85 HRS, ART = 2.86 HRS. Total Bit HRS = 51.26 HRS. Total Jar HRS #14710043 = 189.93 HRS. Total Jar HRS # 14710005 = 83.48 HRS. ACC HRS = 161.02. Max gas observed = 122 units, ECD = 10.55 PPG. Observed drilling Concretions @ 9392'-9397',9443'-9450',9459'-9461', for a total of 14'. Survey @ 9424.34' MD, INC = 90.18 DEG, AZ = 180.67 DEG, 3592.33 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. 12:00 18:00 6.00 9,472 9,879 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9472'-9879' MD (407'). TVD = 3588'. Pumps @ 315 GPMs - 4071 PSI. RPMs = 80, WOB = 8-10K, Torque on = 8K, Torque Off btm = 7K, UP WT = 175K, SO WT = 92K, ROT WT = 122K,. ADT = 3.57 HRS, AST = .81 HRS, ART = 2.76 HRS. Total Bit HRS = 54.83 HRS. Total Jar HRS #14710043 = 193.50 HRS. Total Jar HRS # 14710005 = 87.05 HRS. ACC HRS = 164.59. Max gas observed = 133 units, ECD = 10.58 PPG. Observed drilling Concretions @ 9469'-9484', 9526'-9540', 9810'-9815',985 0'-9852', for a total of 36'. Survey @ 9794.20' MD, INC = 89.50 DEG, AZ = 180.11 DEG, 3586.57 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. Obtain Slow pump rates @ 9872' MD, TVD - 3586'. #1 pump @ 20 SPM - 670 PSI, 30 SPM - 970 PSI. #2 pump @ 20 SPM - 660 PSI, 30 SPM - 1070 PSI. Crew Chan e ..._ ~ .. a. me.. ~ .. ~ m a..... .me. m _ ~~~~ ~ e _ _~__ e ~ ~~ ~ -~ ~ ~ _ s.~ ..r Time Logs Date From To Dur S ~i E,De~th Phase Code 5ubcode T ~~EI I 09/17/2006 18:00 19:00 1.00 9,879 9,880 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9879'-9880' MD (1'). TVD = 3588'. Pumps @ 315 GPMs - 4071 PSI. RPMs = 80, WOB = 8-10K, Torque on = 8K, Torque Off btm = 7K, UP WT = 175K, SO WT = 92K, ROT WT = 122K,. ADT = .08 HRS, AST = 0 HRS, ART = .08 HRS. Total Bit HRS = 54.91 HRS. Total Jar HRS #14710043 = 193.58 HRS. Total Jar HRS # 14710005 = 87.13 HRS. ACC HRS = 164.67. Max gas observed = 133 units, ECD = 10.58 PPG. Observed drilling Concretions @ 9879', for a total of 1'. Survey @ 9794.20' MD, INC = 89.50 DEG, AZ = 180.11 DEG, 3586.57 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. Obtain Slow pump rates @ 9872' MD, TVD - 3586'. #1 pump @ 20 SPM - 670 PSI, 30 SPM - 970 PSI. #2 pump @ 20 SPM - 660 PSI, 30 SPM - 1070 PSI. 19:00 20:45 1.75 9,880 9,880 PROD2 DRILL CIRC T Observed drilling ROP stopped. Could not gain differential pressure. Work drill string and different pump rates to attempt to gain any ROP. No success. Suspect failed mud motor. Pump 35 BBLS of HI VISC weighted sweep, at 310 GPM's - 3850 PSI. Reciprocate & rotate drill string while pump sweep. UP WT = 175K, SO WT = 92K, ROT WT = 122K with 7K torque. Observed 50% increase in cuttings when sweep returned. 20:45 21:45 1.00 9,880 9,375 PROD2 DRILL REAM T Monitor well -static. BROOH for 5 stands @ 25 ftlmin from 9880' - 9375' MD. Observe good hole conditions. Monitor well -static. ' 21:45 00:00 225 9,375 6,405 PROD2 DRILL TRIP T Continue POOH on elevators from 9375' - 8936' MD, wet string. Observe good hole conditions and proper hole fill. Monitor well -static, pump 20 BBL dry job, 10.8 PPG, and continue POOH from 8936' -6405' MD, again with good hole conditions observed with ro er hole fill. 09/18/2006 00:00 03:15 3.25 6,405 1,995 PROD2 DRILL TRIP T Continue POOH from 6405' - 5059'. Pull slow through Window area to 5047' No issues with BHA going through window. Continue POOH from 5047' - 1995'. record T& D parameters as er ri en ineer. __~.,__ m.~ ~r,n Time Logs ~ --- Date From To _ D ur S. E. De th Phase Code Subcode T __ 09/18/2006 03:15 __ 04:15 ___ 1.00 1,995 1,995 PROD2 DRILL OTHR T _ Observed drip pan under rotary table with plugged drains. OBM from drill string would not drain away. Obtain permit, and clean all drains and drip an. 04:15 06:00 1.75 1,995 97 PROD2 DRILL TRIP T Continue POOH from 1955' - 97 MD. Record T&D parameters. Break out, rack back 3 -Non Mag Flex Drill Collars (93.28'), Crossover Sub (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), 48 jnts of 4" XT39 DP (1498.26'), Crossover sub (2.97'), Agitator (8.75'), Shock Sub (8.30'), Crossover sub (3.00'), 48 jnts of 4" XT39 DP (1500.26'), Dailey DNT Mechanical jars (32.24'), 2 jnts of 4" XT39 DP 962.32'), Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50').plug into MWD asembly. Crew Chan e 06:00 07:00 1.00 97 97 PROD2 DRILL PULD T Download MWD assembly. PJSM with crew & Sperry Sun reps. Discuss safety issues and procedure for laying down BHA. 07:00 09:00 2.00 97 0 PROD2 DRILL PULD T Continue POOH, breakout & lay down BHA #7, laying down 6 3/4" Smith bit MDT52 9.84') with 6 x 13's jets for a TFA of .778 sq. in. on a 5" SperryDrill 6/7-6.0 stg w/ ABI motor (32.02'), 4 3/4" Non Mag Float sub (2.33'), 4.870" Welded Blade Stabilizer (5.22'), 4 3/4" MWD terminating sub (1.85'), 4 3/4" Gamma/Res (24.52'), MWD Directional (8.56'), 4 3/4" PWD (10.82'), 4 3/4" TM HOC (11.10'). inspect & grade bit to 1/6/BT/G/X/2/CT/DTF. Observed proper hole fill on TOH. 09:00 09:15 0.25 0 0 PROD2 DRILL OTHR T Clean & clear rig floor of OBM & tools. 09:15 09:30 0.25 0 0 PROD2 DRILL SFTY T Held PJSM with crew and Sperry Sun reps. Discuss safety issues and procedure for making up BHA #8, Geo-Pilot Assembl . 09:30 10:45 1.25 0 90 PROD2 DRILL PULD T Make up BHA #8. Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'), 4 3/4" MWD DM HOC (8.56'), 4 3/4" Smart Stabilizer (3.60'), 4 3/4" MWD Gamma/Res (24.57'), 4 3/4" PWD 10.82' 4 3/4" TM HOC 11.10' . 10:45 12:30 1.75 90 90 PROD2 DRILL PULD T Plug in and Upload MWD assembly. Continue Clean ri floor of OBM. _. ~.....__~,~ ~ ~ ®® ®~~.~-.. -.e ._T _ _~~.. m.~ _~®~ ~ m _.m® ......~.~ _ .v~ ~®sm~~_ .~_ m. ~._~~ ~eee...~__..e_. ~l ~.r_._ ~_ _ _-______ . __..__ _..__..._.~ Time Logs __ Date From To Dur S. E. De th Phase Code Subcode T _ _ 09/18/2006 12:30 13:30 1.00 90 2,160 PROD2 DRILL PULD T Continue make up BHA #8, Make up 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer (5.22'), 3 - Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e to 2160' MD. 13:30 14:30 1.00 2,160 2,160 PROD2 DRILL OTHR T Screw into Top Drive and fill drill string. Attempt to perform Shallow pulse test on BHA -failed. Repeat attempts. Pumps @ 250 GPM's. Blow down TD and ri u to POOH for failed tools. 14:30 16:00 1.50 2,160 90 PROD2 DRILL TRIP T POOH from 2160' - 90' MD. Rack back 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer (5.22'), 3 - Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1 jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e to 2160' MD. 16:00 16:45 0.75 90 90 PROD2 DRILL OTHR T Plug in and download MWD assembly. Clean & clear rig floor of OBM from wet trl 16:45 18:00 1.25 90 0 PROD2 DRILL PULD T Spin & clear OBM mud from Geo-pilot assembly. Breakout & lay down Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'). lay down Geo-pilot & battery pack. Crew Chan e. 18:00 18:45 0.75 0 90 PROD2 DRILL PULD T PJSM with new rig crew. Discuss safety issues and procedure for making up BHA #9. Make up Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'), 4 3/4" MWD DM HOC (8.56'), 4 3/4" Smart Stabilizer (3.60'), 4 3/4" MWD Gamma/Res (24.57'), 4 3/4" PWD 10.82' 4 3/4" TM HOC 11.10' . 18:45 19:15 0.50 90 90 PROD2 DRILL PULD T Plug in and upload MWD assembly. 19:15 19:45 0.50 90 90 PROD2 DRILL PULD T Pull back up hole to the bit. Change out bits as per Co. Rep. Make up 6 3/4" Security FMF3642 PDC bit (1.29') with 3 x 21 jets for a TFA of 1.015 Sq In. ~ e _ee m ....e ~ - --_ _ ___.~A ._.._._ _®s~ ~ _.~. ~~ _ .. am.__ ~ ~_.._.~._.~ _ _ Time Logs __ Date From To Dur S. U ~ E De th Phase Code Subcode T _ 09/18/2006 19:45 21:15 1.50 90 120 PROD2 DRILL PULD T Make up 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer (5.22'), 3 -Non Mag Flex Drill Collars (93.28'). 1 stand of 4" DP. Perform Shallow pulse test on MWD assembly with pumps @ 300 GPM's - 2100 PSI. Good test. 21:15 22:15 1.00 120 120 PROD2 RIGMN SVRG T inspect & Service Top Drive. Inspect mounting plates on motor for TD. ti hten bolts. 22:15 00:00 1.75 120 3,760 PROD2 DRILL TRIP T Continue trip in hole from 120' - 3940'. Make up remaining BHA with 37 stands of 4" DP (3467.56'), Crossover sub (2.97'), Dailey DNT Mechanical jars (32.24'), 2 jnts of 4" XT39 DP (62.32'), Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Total BHA = 3940.53'. 09/19/2006 00:00 06:00 6.00 3,760 7,035 PROD2 DRILL TRIP T Continue trip in hole with BHA #9 from 3760' - 5047'. Pump to verify Geo-pilot deflection at zero. Work Drill string through window area, observing haging up on Bit & Stabilizers. Continue TIH, tagging, hanging up & firing jars in spots @ 5253', 5470' and different areas to 7035' MD. Screw into Top drive @5470' pumping and observing deflection at 125%. Send commands to zero defletion. Continue trip in hole having to ream in spots from 5047' - 7035' MD, until observe needing to pump almost every stand. Pumps @ 315 GPM's - 2150 PSI, 50 RPM's with 5K for ue. Crew than e 06:00 06:30 0.50 7,035 7,410 PROD2 DRILL TRIP T Continue trip in hole 7035' - 7410' MD on elevators. Observed continued han in u with over ull. 06:30 11:45 5.25 7,410 9,880 PROD2 DRILL REAM T Wash & ream each stand from 7410' - 9880' MD. Pumps @ 330 GPM's - 3100 PSI. 5-8K WOB, with 90-100 RPM's. ROT WT = 120K. e.. ®~ e m ..ee~~~ Time Logs _ -_ -- -- Date From To DUf S. G i E. De th F~hase Code Subcode T 09/19/2006 11:45 12:00 0.25 9,880 9,884 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9880'- 9884' MD (4'). TVD = 3588'. Pumps @ 345 GPMs - 3430 PSI. RPMs = 110, WOB = 2-8K, Torque on = 9K, Torque Off btm = 8K, UP WT = 172K, SO WT = 92K, ROT WT = 122K,. ADT = .15 HRS, Total Bit HRS = .15 HRS. Total Jar HRS #14710043 = 198.73 HRS. Total Jar HRS # 14710005 = 87.28 HRS. ACG HRS = 164.92. Max gas observed = 43 units, ECD = 11.1 PPG. Survey @ 9812.24' MD, INC = 88.28 DEG, AZ = 180.60 DEG, 3586.92 TVD. Mud WT = 8.8 PPG Visc = 70, YP = 21, PV = 17. Gels = 28/30. Obtain Slow pump rates @ 9844' MD, TVD - 3586'. #1 pump @ 20 SPM - 570 PSI, 30 SPM - 820 PSI. #2 pump @ 20 SPM - 570 PSI, 30 SPM - 830 PSI. 12:00 18:00 6.00 9,884 10,501 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9884'- 10501' MD (617'). TVD = 3613'. Pumps @ 340 GPMs - 3650 PSI. RPMs = 110, WOB = 2-10K, Torque on = 8K, Torque Off btm = 8K, UP WT = 185K, SO WT = 85K, ROT WT = 121 K,. ADT = 4.25 HRS, Total Bit HRS = 4.25 HRS. Total Jar HRS #14710043 = 202.98 HRS. Total Jar HRS # 14710005 = 91.53 HRS. ACC HRS = 169.07. Max gas observed = 82 units, ECD = 11.2 PPG. Observed drilling Concretions @ 9920'-9923',10336'-10339',10426'-1043 0', for a total of 10'. Survey @ 10466.42' MD, INC = 91.10 DEG, AZ = 180.78 DEG, 3611.83 TVD. Mud WT = 8.8 PPG Visc = 69, YP = 21, PV = 17. Gels = 28/30. Obtain Slow pump rates @ 9844' MD, TVD - 3586'. #1 pump @ 20 SPM - 570 PSI, 30 SPM - 820 PSI. #2 pump @ 20 SPM - 570 PSI, 30 SPM - 830 PSI. Crew Chan e _®mm ®. ~ . ~ ~ ~ _ ~ ~~.~~. ~~~~ ... A~.~ m~m.~ ~.__., wde. e ~. ~. ~ ~s ~ ..~aaa ~ Time Logs ~ Date From To Dur S. E De th Fhase Code Stibcode T 09/19/2006 18:00 00:00 6.00 10,501 11,020 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 10501'-11020' MD (519'). TVD = 3593'. Pumps @ 340 GPMs - 3610 PSI. RPMs = 110, WOB = 8-10K, Torque on = 9K, Torque Off btm = 8K, UP WT = 185K, SO WT = 75K, ROT WT = 120K,. ADT = 4.59 HRS, Total Bit HRS = 8.99 HRS. Total Jar HRS #14710043 = 207.57 HRS. Total Jar HRS # 14710005 = 96.12 HRS. ACC HRS = 173.66. Max gas observed = 162 units, ECD = 11.93 PPG. Observed drilling Concretions @ 10982'-10984',10994'-10995',11052'-11 063',11128'-11130', for a total of 16'. Survey @ 10934.25' MD, INC = 92.18 DEG, AZ = 180.08 DEG, 3595.80 TVD. Mud WT = 8.9 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. 09/20/2006 00:00 06:00 6.00 11,020 11,626 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 11020' - 11626' MD (606'). TVD = 3592'. Pumps @ 340 GPMs - 3300 PSI. RPMs = 100, WOB = 8-10K, Torque on = 9K, Torque Off btm = 7K, UP WT = 185K, SO WT = 75K, ROT WT = 120K,. ADT = 4.18 HRS, Total Bit HRS = 13.17 HRS. Total Jar HRS #14710043 = 211.75 HRS. Total Jar HRS # 14710005 = 100.30 HRS. ACC HRS = 177.84. Max gas observed = 145 units, ECD = 11.57 PPG. Observed drilling Concretions @ 11052'-11063',11128'-11130',11309'-11 314',11393'-11402', for a total of 27'. Survey @ 11591.66' MD, INC = 91.89 DEG, AZ = 175.37 DEG, 3595.58 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30131. Pump Hi Visc weighted sweep @ 11400' MD, observe 75% increase in cuttings on shakers when returned. Obtain Slow pump rates @ 11153' MD, TVD - 3590'. #1 pump @ 20 SPM - 620 PSI, 30 SPM - 890 PSI. #2 pump @ 20 SPM - 620 PSI, 30 SPM - 890 PSI. Crew Chan e ®e...~ __ . s_e ..~ _.~ .__.._. ,. ~ . m ...e.. ~ ® ...e.®..e.._ ~ . ______,e~ m.®e®. ~ ~ _ <~ 'rI Time Logs _ _ :Date_ From To Dur S. ~ E. De' th Phase Code Subcode T 09/20/2006 06:00 12:00 6.00 11,626 11,907 PROD2 DRILL DDRL P _ Directional Dril16 3/4' hole in the B Lateral from 11626'-11907' MD (281'). TVD = 3586'. Pumps @ 340 GPMs - 3775 PSI. RPMs = 80-120, WOB = 2-8K, Torque on = 9K, Torque Off btm = 7K, UP WT = 190K, SO WT = 85K, ROT WT = 120K,. ADT = 4.77 HRS, Total Bit HRS = 17.94 HRS. Total Jar HRS #14710043 = 216.52 HRS. Total Jar HRS # 14710005 = 105.07 HRS. ACC HRS = 182.61. Max gas observed = 69 units, ECD = 11.53 PPG. Observed drilling Concretions @ 11724'-11738',11744'-11762', for a total of 32'. Survey @ 11874.01' MD, INC = 92.63 DEG, AZ = 181.69 DEG, 3586.20 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. 12:00 16:00 4.00 11,907 12,242 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 11907'-12242' MD (335'). TVD = 3580'. Pumps @ 340 GPMs - 3750 PSI. RPMs = 80-130, WOB = 2-12K, Torque on = 9K, Torque Off btm 7K, UP WT = 210K, SO WT = 85K, ROT WT = 120K,. ADT = 1.79 HRS, Total Bit HRS = 19.73 HRS. Total Jar HRS #14710043 = 218.31 HRS. Total Jar HRS # 14710005 = 106.86 HRS. ACC HRS = 184.40. Max gas observed = 79 units, ECD = 11.45 PPG. Observed drilling Concretions @ 11985'-11987',12138'-12143',12163'-12 165', for a total of 9'. Survey @ 12148.86' MD, INC = 91.34 DEG, AZ = 177.58 DEG, 3584.64 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. Obtain Slow pump rates @ 12075' MD, TVD - 3584'. #1 pump @ 20 SPM - 660 PSI, 30 SPM - 920 PSI. #2 pump @ 20 SPM - 650 PSI, 30 SPM - 910 PSI. Observe 23 deg dogleg @ 12152', and then MWD trouble. Decision to call TD in lateral. 16:00 16:15 0.25 12,242 12,184 PROD2 DRILL REAM P Back ream out of hole from 12242' -12184'. pumps @ 340 GPM's - 3750 PSI, 100 RPMs, with for ue 8K. 16:15 16:30 0.25 12,184 12,094 PROD2 DRILL TRIP P POOH on elevators from 12184'- 12094'. UP WT = 210K, SO WT = 90K. 16:30 18:00 1.50 12,094 12,094 PROD2 DRILL CIRC P Pump 40 BBLS Hi Visc weighted sweep, 10.7 PPG, 200 Visc, @ 330 GPM's - 3780 PSI. Reciprocate & rotate drill string at 100 RPM's with 8K torque. Monitor well -static. Crew Chan e. W ~...ew ~_ ~ _ ~~_ ~ _.__. ~ . m-~ _ ~ _.__ .. ~ m~ n~ ~ .._. ~~. - -_~_ ~ ~_.._.,~....~ ~ ~. ~._ ___ Time Logs -~- Date From To Dur S. E_ Depth Phase Cede Subcode T D~IPI 09/20/2006 18:00 21:00 3.00 12,094 10,750 PROD2 DRILL REAM P BROOH from 12094' - 11430'. Attempted to POOH on elevators, observed tight hole, continue BROOH from 11430' - 10750'. Pumps @ 340 GPM's - 3600 PSI. 100 RPM's. Circulated strokes = 2 btms up, before attem t POOH on elevators. 21:00 22:00 1.00 10,750 10,200 PROD2 DRILL TRIP P POOH on elevators from 10750' - 10200'. Observe good hole conditions and proper hole fill. Monitor well - static. 22:00 00:00 2.00 10,200 7,900 PROD2 DRILL TRIP P Pump dry job. Blow down TD & lines. Continue POOH on elevators from 10200' - 7900' MD. Observe good hole conditions and ro er hole fill. 09/21/2006 00:00 02:15 2.25 7,900 4,972 PROD2 DRILL TRIP P Continue POOH on elevators from 7900' - 4972' MD. Observe good hole conditions and ro er hole fill. 02:15 03:30 1.25 4,972 4,972 PROD2 DRILL CIRC P Circulate 40 BBL Hi Visc weigted sweep (10.8 PPG - 170 Visc) @3410 GPM's - 2600 PSI. 100 RPM's with 5K torque. Reciprocate 7 rotate drill string while pump. Observed no significant increase in cuttings on return of swee . 03:30 05:15 1.75 4,972 4,972 PROD2 RIGMN SVRG P Slip & cut 105' of drilling line. Inspect & adjust brakes on draw works. Ins ect & service To Drive. 05:15 06:00 0.75 4,972 6,000 PROD2 DRILL TRIP P Trip back in hole from 4972' - 6000' MD. Observe proper hole fill. Observed no issues when BHA going through window area. UP WT = 145K, SO WT = 105K. Obtain T&D parameters as er ri en ineer. Crew Chan e 06:00 09:15 3.25 6,000 9,942 PROD2 DRILL TRIP P Continue trip in hole from 6000' - 9942' MD. Obtain T&D parameters as per rig engineer. Every 5 stands in open hole. Observed good hole conditions, filling drillin drill strin eve 25 stands. 09:15 12:00 2.75 9,942 11,709 PROD2 DRILL REAM P Ran out of downweight. Make Top Drive connection. Fill drill string. Wash & ream from 9942' - 11709'. Pumps @ 126 GPM - 1000 PSI & 60 RPM's 12:00 12:30 0.50 11,709 12,094 PROD2 DRILL REAM P Continue wash & ream in hole from 11709' - 12094' MD. Pumps @ 126 GPM - 1000 PSI & 60 RPM's 12:30 14:15 1.75 12,094 12,094 PROD2 DRILL CIRC P Establish Circulation rates of 340 GPM's- 4000 PSI. 140 RPM's, and pump a Weighted Hi Visc sweep. Reciprocate & rotate drill string while pumping. UP WT = 124K, SO WT = 104K, ROT WT = 112K. Circulate swee + 2 Btms u until clean. ~~ _. _ - ~. tF ~s~ «~ r ~_ m_ _____....... ~ _._ ~_a__ ®..___._. _ ____,. e.e..~.~.___m__ ~_.. ~ ~.~... M......_ . e_ ~ . ~_._. m.. ~ Time Los _ _ Date From To Dur S. ~ E. De #h Phase Code Subco de T 09/21/2006 14:15 15:00 0.75 12,094 12,094 PROD2 DRILL _ CIRC P Rig up and displace production hole section to 8.9 PPG SFMOBM, 350 BBLS. Chase with 25 BBL Dry job. Calculated top of SFMOBM = 4500' MD 15:00 15:15 0.25 12,094 12,094 PROD2 DRILL TRIP P Monitor well -static. Drop 2 1/4" drift with tail wire in DP. 15:15 18:00 2.75 12,094 8,162 PROD2 DRILL TRIP P POOH on elevators from 12094' - 8162' MD. Observed good hole conditions and no overpull issues.Observed ro er hole fill. Crew Chan e 18:00 20:00 2.00 8,162 4,980 PROD2 DRILL TRIP P Continue POOH with BHA #9 from 8162' - 4980'. observed no issues going throuh window area with BHA. Monitor well -static. 20:00 20:30 0.50 4,980 3,940 PROD2 DRILL TRIP P Continue POOH from 4980' - 3940' . Stand back Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Pull 2 1/4" Drift from assembly, and drop in remainin BHA with tail wire. 20:30 22:00 1.50 3,940 295 PROD2 DRILL TRIP P Continue POOH from 3940' - 295' MD. Racking back 37 stands of 4" DP (3467.56'), Crossover sub (2.97'), Dailey DNT Mechanical jars (32.24'), 2 "nts of 4" XT39 DP 62.32' . 22:00 22:45 0.75 295 97 PROD2 DRILL PULD P Continue POOH breakout & lay down 4 3/4" Welded Blade stabilizer (5.22'), 3 -Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e 22:45 23:15 0.50 97 97 PROD2 DRILL PULD P Plug in and download MWD asembly. prepare rig floor for next run with 4 1/2" liner. 23:15 00:00 0.75 97 25 PROD2 DRILL PULD P Continue POOH, Breakout & lay down 4 3/4" MWD terminating sub (1.85'), 4 3/4" Gamma/Res (24.52'), MWD Directional (8.56'), 4 3/4" PWD 10.82' , 4 3/4" TM HOC 11.10' . 09/22/2006 00:00 00:15 0.25 25 0 PROD2 DRILL PULD P Continue POOH breakout & lay down 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'). lay down Geo-pilot & battery pack, 4 3/4" Non mag float sub (2.33'). Inspect & au a bitto 1/1/BT/A/X/I/NO/DTF. 00:15 00:45 0.50 0 0 COMPZ CASIN( RURD P Clean & clear rig floor area. Send tools out. Rig up liner running tools for 4 1/2" Slotted liner. Pick up Tongs, elevators, and sli s. ~~ .__~ ® ~~ _ e ~. ~® j. ~ ._... ~. ®.~ _~ ~ ®® . a ®_ ma~ ~ _ ~ Time Logs _ _ Date From To Dur S: ~ E. De th Phase Code Subcode T 09/22/2006 00:45 01:30 0.75 0 0 COMPZ CASIN< SFTY P _,_ Held PJSM with rig crew, GBR rep, and BOT rep. Discuss safety issues and procedure for picking up 4 1/2" slotted liner. Open blind rams and monitor well -static. 01:30 06:00 4.50 0 6,402 COMPZ CASIN( RNCS P Make up 4 1/2" Siver Bullet Shoe (1.67'), 1 -jnt of 4 1/2" 12.6# IBT blank (31.17'), and 4 1/2" XO pup to BTC (2.06'). Continue make up 4 1/2" Slotted /Blank liner as per detail. Run from surface to 6402' MD. Obtain T&D parameters as per rig engineer. MU TQ = 4500 FUlbs. MU TQ w/ TQ rings = 5K FT/LBs. Observe no issues as Shoe passing through window area. Crew Chan e 06:00 07:00 1.00 6,402 6,857 COMPZ CASIN( RNCS P Continue run 4 1/2" Slotted liner from 6402' - 6857'. Observed proper hole fill. No o en hole issues. 07:00 07:30 0.50 6,857 6,857 COMPZ CASIN( RNCS P Change elevators & power tongs. Make up 5 1/2" Hydril 521 x 4 1/2" BTC XO bushing (1.42') with 4 1/2" BTC pup (3.80'), 1 joint of 5 1/2" Hydril 521 Blank (36.60'), 5 1/2" Hydril 521 pup (8.98'), and BOT "H R" liner setting sleeve (12.64'}, with running tool & XO (6.44',2.99'). Rig down GBR casing equipment. Clean & clear floor area for TIH w/ DP. 07:30 12:00 4.50 6,857 11,700 COMPZ CASIN< RUNL P obtain Up/DN weights with liner. UP WT = 125K, SO WT' = 95K. ROT WT = 109K. TIH with 4 1/2" Slotted liner on DP form 6857' - 10600' MD. Running speed as per BOT rep. Rotate liner in hole from 10600' - 11700' MD at 20 RPM's - 5K t . 12:00 13:15 1.25 11,700 12,093 COMPZ CASIN( RUNL P Continue RIH with Slotted liner rotating liner from 11700' - 12093' MD. 25 RPM's - 7K for ue. Set liner on de th. 13:15 14:15 1.00 12,093 12,093 COMPZ CASIN( OTHR P Drop 29/32" Ball, pumping @ 2.5 BPM, observing ball landed and pressuring up to 3500 PSI. Continue pressure to 4000 PSI, releasing liner setting tool with the top @ 5244' MD. Bleed all pressures. Pull up to observe wei ht loss and free from liner. 14:15 14:30 0.25 5,244 4,947 COMPZ CASIN( RUNL P POOH with DP from 5244' - 4947' MD. Observe wet drill strin . 14:30 15:00 0.50 4,947 4,947 COMPZ CASIN( CIRC P Circulate bottoms up @ 300 GPM's - 1075 PSI. Monitor well -static. 15:00 15:30 0.50 4,947 4,947 COMPZ CASIN( RUNL P Pump dry job. Blow dow TD & lines. Dro 1.93" drift in DP with tail wire. 15:30 18:00 2.50 4,947 0 COMPZ CASIN( RUNL P POOH with DP from 4947' -surface. Inspect, breakout and lay down BOT runnin tools. All ood. Crew Chan e. 18:00 19:00 1.00 0 0 COMPZ CASIN( RUNL P Finish laying down running tools. Clean & clear ri floor area. kgy R -__ _ _ _ _ Time Logs _ _ I Date From To Dur S; E. Depth Phase Code 5ubcode T 09/22/2006 19:00 _ 19:45 0.75 0 0 COMPZ RIGMN RGRP T ~ _ _ Change out HI -LOW valve for draw works drum clutch. Pull tools to flooe for Whi stock retrieval run. 19:45 21:45 2.00 0 0 COMPZ RIGMN SVRG P Change out saver sub on Top Drive. 21:45 22:30 0.75 0 0 COMPZ STK PULD P Make up Baker retrieving hook assembly. make up Retrieving hook (7.50'), 1-jnt of 4" HWDP (37.28'), 4 3/4" Bumper jar (7.73'), 4 3/4" Oil Jar (11.15'), crossover sub (2.99') and 3 stands of h brid ush i e 278.43' . 22:30 00:00 1.50 0 2,600 COMPZ STK TRIP P Trip in hole with retrieving assembly from surface to 2600' MD. Observe ro er hole fill. 09/23/2006 00:00 02:15 2.25 2,600 5,052 COMPZ STK TRIP P Continue TIH with BOT whipstock retrieving tool from 2600 - 5052'. UP WT = 140K, SO WT = 100K. Observed ro er hole fill on TIH. 02:15 05:00 2.75 5,052 5,052 COMPZ STK CIRC P Locate wash port in tool joint to the slot in whipstock. Wash slot with pumps @ 5 BPM - 1650 PSI. Continue to wash & attempt to engage slot with hook. repeat attempts to engage working string in 1/4 turn increments. Wash slot numerous times to observe hooking Whiopstock pulling 50K over allowing jars to bleed. Slack off and re-cock jars, pulling to 75K over to fire jars and observe assembly free with 8K added wei ht or dra . 05:00 05:15 0.25 5,052 4,960 COMPZ STK OWFF P Pull 1 stand slow observing fluid falling in well bore, and rack back 1 stand. Make To Drive connection. 05:15 06:00 0.75 4,960 4,960 COMPZ STK TRIP P Circulate bottoms up at 5.5 BPM - 1000 PSI as per BOT rep. Monitor well - static. Crew chan e 06:00 06:30 0.50 4,960 4,960 COMPZ STK CIRC P Pump dry job, blow down Top Drive & lines. 06:30 10:00 3.50 4,960 337 COMPZ STK TRIP P POOH with Whipstock Retrieving assembly and whipstock from 4960' - 337'. Observed proper hole fill. No swabbin . 10:00 12:00 2.00 337 0 COMPZ STK PULD P Brekaout & lay down Fishing BHA. Lay down Retrieving hook (7.50'), 1-jnt of 4" HWDP (37.28'), 4 3/4" Bumper jar (7.73'), 4 3/4" Oil Jar (11.15'), crossover sub (2.99') and rack back 3 stands of hybrid push pipe (278.43'). Continue breakout & lay down Whipstock assembly with jewelry and s ace out i e. 12:00 12:30 0.50 0 0 COMPZ STK PULD P Continue POOH breakout & lay down Whipstock assembly with jewelry and space out pipe. Observed seal in good shape on seal assembly. Whipstock slide was in ood sha e. r ,~.~~ I Time i_o s -- date From To Dur S. E. De th Phase Code Subcode T L 09/23/2006 12:30 _ 13:00 0.50 0 0 COMPZ STK PULD P Clean & Clear Rig Floor area and send tools out. 13:00 13:15 0.25 0 0 COMPZ CASIN( RURD P Rig up to run Hook Hanger assembly. Rig up Tongs and elevators. Pull e ui ment to ri floor. 13:15 13:30 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with crew, GBR, BOT & Sperry Sun reps. Discuss safety issues and procedure for making up Hook Han er assembl . 13:30 15:00 1.50 0 259 COMPZ CASIN( PUTB P Make up Hook hanger asembly. make up 7 5/8" x 4 1/2" Baker Model B-1 HH for LEM (16.71', 6.12'), 4 1/2" pup (3.85'), 4 1/2" Blankjnt (39.86'), 4 1/2" pup (5.75'), baker Payzone External Casing Packer (13.06'), 4 1/2" Pup (3.06'), 4 1/2" Pup (3.80'), 2 -jnts Slotted liner (86.68'), 4 1/2" Crossover jnt (42.71'), and 4 1/2" Bent joint 28.25' .Total BHA = 258.93' 15:00 15:30 0.50 259 259 COMPZ CASIN( PUTB P make up Sperry Sun MWD Slim Hole assembly and orient MWD to Hook han er hook. 15:30 16:15 0.75 259 259 COMPZ CASIN< PUTB P Rig down all casing running equipment. Clean & clear rig floor area of OBM. RU to TIH with DP. 16:15 17:30 1.25 259 2,300 COMPZ CASIN( RUNL P Trip in hole with Hook hanger assembl from 259' - 2300'. 17:30 17:45 0.25 2,300 2,300 COMPZ CASIN( RUNL P Perform Shallow pulse test on MWD tools. Good test. 17:45 18:00 0.25 2,300 2,438 COMPZ CASIN( RUNL P Continue TIH with B lateral Hook Haanger assembly from 350 - 2438'. Crew Chan e 18:00 20:30 2.50 2,438 5,047 COMPZ CASIN( RUNL P Continue TIH with B Lateral Hook Han er Assembl from 2438' - 5047'. 20:30 21:45 1.25 5,047 5,296 COMPZ CASIN( RUNL P Attempt to run Shoe through window and observed tagging up on the A Lateral Crossover @ 5200'. Repeat attempts 4 times rotating string 1/4 RH turns to finally observe shoe into open hole. UP WT = 170K, SO WT = 140K. ~~ _- ~.~~ __ _____~.a s..~ _ ~____.__.~~ ®~~® ~ ~..m _ _q~ ___ _~ ®.ae~---~_a. 1 t ~~t... ,., ~ ,} ~~ Time Logs - --- __ __ Date From To Dur S E. De th Phase Code Subcode T~ 09/23/2006 21:45 22:45 1.00 5,296 5,296 COMPZ CASIN( OTHR P Pick up single DP. Continue RIH to 15' above Window. Pump to orient Hook to 26 Deg left. Slack off, observe Hook engaged window and MWD indicated set down @ 9 Deg Right. Pull up to orient 180 Degrees out, and slack off to tag Crossover in B Lat Setting Sleeve on depth @ 5303' MD. Pull back up above window, and re-orient Hook to 23 Deg, Left. Slack off observing Hook engaged window once again, and corrected MWD toolface indicated 12 Deg right on the final set down w/ 30K set down on Hook. Pumps @ 117 GPM - 1000 PSI. Found Bottom of window and hooked hanger @ 5062.87' MD (2.87' low). Drop 29/32" ball down drill string and chase with pumps @ 2.5 BPM - 1000 PSI until observed ball landed. 22:45 00:00 1.25 5,296 5,296 COMPZ CASIN( OTHR P With ball seated, pressure to 2800 PSI, to release setting tool and inflate ECP @ 5118.45' MD. Allow pressure to bleed to 2000 PSI. Hold 10 Minutes. Pressure to 2800 PSI observing 1.2 strokes or .14 BBIs to inflate as per BOT rep. Mule shoe @ 5296.01' MD = 7' from crossover. 09!24/2006 00:00 00:45 0.75 5,060 5,060 COMPZ CASIN( RUNL P Bleed all pressures. Rack back 1 stand, and lay down single joint. Pump Dry Job. Momitor well -static. Blow down To drive & lines. 00:45 03:15 2.50 5,060 90 COMPZ CASIN< RUNL P POOH with setting tools from 5060' - surface. Observe ro er hole fill. 03:15 04:15 1.00 90 0 COMPZ CASIN( RUNL P Breakout & lay down Running & setting tools for Hook Hanger assmy. La down Slim hole MWD assembl . 04:15 05:00 0.75 0 0 COMPZ CASIN( OTHR P Clean & clear rig floor area. Held PJSM with crew. Discuss Safety issues and procedure for making up B lateral LEM tools. 05:00 06:00 1.00 0 369 COMPZ CASIN( RUNL P MU 4 1/2" Bent joint (43.25') with Seals Assembly (3.25'). Run 2 joints of 4 1/2" 12.6 L80 IBT TBG (62.17'), Camco DB-6 Nipple with 3:563" ID profile (1.55'), Pup jnt (9.80'), LEM assembly (35.17'),Pup Jnt (3.83'), XO Bushing (1.44'), 109-47 Casing Seal Bore receptacle (19.69'), 7 5/8" ZXP Liner Top PKR (19.08') and running & setting tools with XO.. Total BHA = 369.05' Crew Chan e 06:00 07:00 1.00 369 369 COMPZ CASIN( RUNL P Continue MU remaining LEM assembly. rig down casing running tools. Clean & clear rig floor of OBM & tools. ____- ~.a..s._..e®Re Time Logs Date From To Dur S. E Depth Phase Code 5~ibcode T ~I~l 09/24/2006 07:00 12:00 5.00 369 5,191 COMPZ CASIN( RUNL P TIH with LEM runing assembly 25-30 ft/minute as per BOT rep from 369' - 5128'. Make Top Drive connection, observe seals going through B lateral Hook Hanger with 20k drag, latching up on depth as planned with seals @ 5191.65' MD. Top of ZXP PKR at 4837.00' MD. 12:00 13:00 1.00 5,191 4,837 COMPZ CASIN( RUNL P Drop 1 3/4" ball, allowing to fall chasing it with pumps @ 2.5 BPM - 250 PSI. Observed ball seated. pressuring to 4000 PSI to release setting tool. Pick up to verify free movement, and Close annular bag. Pressure down annulus to 1000 PSI for 10 Minutes. Good test. All pressures and tests recorded on chart. 13:00 13:15 0.25 4,837 4,800 COMPZ CASIN( RUNL P Pull running & setting tool out of packer top, and rig down all pressure test a ui ment. 13:15 14:00 0.75 4,800 4,800 COMPZ CASIN( CIRC P Circulate bottoms up with pumps at 7 BPM - 1200 PSI. Monitor well -static. Pum d 'ob. 14:00 14:15 0.25 4,800 4,800 COMPZ CASIN( OTHR P Blow down Top drive and lines. Prep ri floor for POOH. 14:15 16:15 2.00 4,800 0 COMPZ CASIN( RUNL P POOH from 4800' to surface with running & setting tools. Observe proper hole fill. 16:15 17:00 0.75 0 0 COMPZ CASIN( RUNL P Breakout, inspect and lay down running & setting tools as per BOT re . 17:00 17:15 0.25 0 0 PROD3 STK PULD P Clear & clean floor area from OBM. Lay down tools. Pull all tools to floor for whi stock run. 17:15 18:00 0.75 0 0 PROD3 STK PULD P Held brief PJSM. Discuss picking up whipstock assembly with seals & s ace out i e. Crew Chan e 18:00 19:30 1.50 0 497 PROD3 STK PULD P Mu Whipstock assembly. Pick up Seals with No-Go (4.21'), 4 3/4" Unloader sub (5.19'), 3 1/2" pup joint (11.85'), 2 -joints of 3 1/2" drill pipe (62.30'), 4 3/4" Double pin blanking sub (1.02'), 7 5/8" Bottom Trip Anchor (3.23'0, 4 3/4" Shear Disconnect (2.63'), 4 5/8" Drain sub (1.03'), 4 11/16" Debris barrier sub (1.88'), 7 5/8" Whipstock slide (15.45'), MU 6.156" Starting Mill (1.10'), 6 5/16" Lower mill (5.5'), 6 3!4" Upper mill (5.84'), 1 joint of 3 1/2" HWDP 29.78' . 19:30 20:30 1.00 497 497 PROD3 STK PULD P Make up 4 3/4" Float sub (2.35'), MWD assembly (56.32') and orient MWD to Whi stock face. 20:30 21:00 0.50 497 497 PROD3 STK PULD P Plug in and upload MWD assembly. ~m.m. __ ~~m ~ ee e...m ®em ~. m~~m ~ ___.. ~®.m~ _ ~__w_~ ~_ ~_--~~~.~~.~ ~~ ;~ ~~~ e n ~_. ..~ w_~..~ ~~ ___ m.~~-. ___~_m ~ __.. ~ m_......___ .... ~.®. ~-.____~_ ~ ~.__..__ ..._. _...e~-~__ __ Time Logs ~ _ Date From To Dur S E. De th Phase Code Subcode T~ 09/24/2006 21:00 21:30 0.50 497 497 PROD3 STK PULD P Continue make up 4 3/4" Bumper jar (7.73'), Crossover sub (2.99'), and 3 stands of 4" Hybrid push pipe 278.43' .Total BHA = 496.54'. 21:30 21:45 0.25 497 497 PROD3 STK TRIP P Run 1 stand of drill pipe & perform shallow pulse test on MWD. Good test with um s 300 GPM-1000 PSI. 21:45 22:15 0.50 497 620 PROD3 STK TRIP P Pick up 2 stands of Hybrid push pipe. Blow down Top drive & lines. Held PJSM with crew & WWT rep. Discuss saftey issues and procedure for moving Su er Sliders on each 'oint of DP. 22:15 00:00 1.75 620 1,433 PROD3 STK TRIP P TIH with 7 5/8" Whipstock assembly, 2 minutes per stand as per BOT rep from 496' - 1433' MD. Move each super slider up 1 ft from last position to prevent wear on DP. Observe proper hole fill on TIH. 09/25/2006 00:00 04:00 4.00 1,433 4,516 PROD2 FISH TRIP P Continue TIH with 7 5/8" Whipstock assembly, 2 minutes per stand as per BOT rep from 1433' - 4516 MD. Move each super slider up 1 ft from last position to prevent wear on DP. Observe ro er hole fill on TIH. 04:00 04:45 0.75 4,516 4,556 PROD2 FISH OTHR P Perform MAD PASS as per geoligist from 4516' - 4556' Bit depth with pumps at 300 GPM's - 2000 PSI. Observed Lo at 2' Dee from Ian. 04:45 05:30 0.75 4,556 4,837 PROD2 FISH TRIP P Continue TIH with 7 5/8" Whipstock assembly, 2 minutes per stand as per BOT rep from 4556' - 4837' MD. Observe ro er hole fill on TIH. 05:30 06:00 0.50 4,837 4,837 PROD2 FISH OTHR P Make Top drive Connection. Pumps at 300 GPM's - 2100 PSI. Orient Whipstock face @ 13 Deg Left of High Side as per BOT rep, and Sperry Sun DD. Observe seal going into liner top at 4837'. Set down to set trip anchor @ 12K, and pick up to verify set with 10K overpull. Set down 35K to shear bolt. Pick up to neutral position and rotate drill string free with 5K torque. Whipstock top = 4730.5' MD. D Sand top = 4730' as per Geologist. Crew Chan e 06:00 11:15 5.25 4,730 4,771 PROD3 FISH MILL P Mill window from 4730' - 4743' in 3.75 HRS, Continue to mill open hole to 4771' in 1.6 HRS. AVG ROP = 3.47 V \J ~-- ff/hr in the window area. Gauged open hole = 16' below window. Pumps @ 300 GPM's - 1900 PSI. UP WT = 143K, SO WT = 113K, ROT WT = 127K. 100 RPM's with 2-8K torque. WOB = 2-5K. Pump 40 BBL sweep at bottom of window. ~~ ~e ~. ®a. a ®~.a~. ~~ ~, 1 i~~ ~____ ~. ~__~ ~..... ~-~ ~._.~ ~ ~m~~.~~____ __...~.... ,,,~ - W .ms..m__._..~ ..... ~__... ~m_.~ _w.... ~ -_._~ ~ __ - -- _- Time Logs Date From To Dur S. E. De th Phase Code Subcode T 09/25/2006 11:15 12:15 1.00 4,771 4,771 PROD3 FISH MILL P Pump 40 BBL Hi Visc weighted sweep at 4771' MD, while working mills through window area until cleaned up. Work window without pumps, window clean in and out. 12:15 13:00 0.75 4,771 4,771 PROD3 FISH MILL P Monitor well -static. Pump dry job. Blow down To Drive & lines. 13:00 14:45 1.75 4,771 496 PROD3 FISH TRIP P POOH from 4730' - 390'. Observe proper hole fill. SIMOPS: Test Choke manifold & floor valves for scheduled BOP test while POOH. All tests recorded on chart. 14:45 16:30 1.75 496 0 PROD3 FISH PULD P Stand back 3 -stands of Hybrid push pipe (278.43'). Breakout & lay down Milling BHA. Lay down 6.156" Starting Mill (1.10'), 6 5/16" Lower mill (5.5'), 6 3/4" Upper mill (5.84'), 1 joint of 3 1/2" HWDP (29.78'), 4 3/4" Float sub (2.35'). Plug in and download MWD assembly. Rack Back MWD assembly (56.32') in derrick, Lay down 4 3/4" Bumper jar (7.73'), Crossover sub (2.99'). inspect & gauge upper mill to full au a of 6 3/4". 16:30 18:00 1.50 0 0 PROD3 FISH OTHR P Make up BOP Stack washing tool. Flush BOP stack while functioning HCR valves and manuals, Functioned all rams, & annular bag. Blow down all lines. Lay down stack washing assembl .Crew Chan e 18:00 21:45 3.75 0 0 PROD3 WELCT BOPE P Pull Wear Bushing. Rig up to complete scheduled BOP test. Install test joint, test plug & test BOP's & Top Drive valves. Perform Accumulator test. First 200 PSI = 50 secs, full charge = 3 min-20 sec. AVG for 5 Nitrogen bottles pressure = 2950 PSI. Rig down all test e ui ment. 21:45 22:00 0.25 0 0 PROD3 DRILL PULD P Clean & clear floor area. Send tools out, and pull tools to floor for next BHA. 22:00 22:15 0.25 0 0 PROD3 DRILL OTHR P Blow down Top Drive and all lines. Line up Choke manifold valves, and Stack valves. 22:15 22:45 0.50 0 0 PROD3 DRILL SFTY P Held PJSM with new crew, Sperry Sun DD &MWD reps. Discuss safety issues and procedure for making up BHA #12, 6 3/4" Geo-pilot drilling assembl . 22:45 00:00 1.25 0 0 PROD3 DRILL PULD P Make up 6 3/4" Drilling assembly. Make up 6 3/4" Security PDC FMF 36142 bit (1.30') with 3x21 jets for a TFA of 1.015 sq. in., 5200 Seies Geo-Pilot Assembly (16.18'), 4 3/4" Non MAg Geo Pilot Flex collar 11.55' . ~~~s~ , ~i -- - Time Logs ---- - _ - ~ . Date From To Dur S. E. De th Phase Code..: Subcode T 09/26/2006 00:00 01:30 1.50 30 87 PROD3 DRILL PULD P Continue make up 4 3/4" Directional HOC (8.56'), 5 1/4" Smart Stabilizer (3.59'), 4 3/4" Gamma/Res (24..51'), 4 3/4" PWD (10.79'), 4 3/4" TM HOC 10.61' .Chan a out Pulsar & Float. 01:30 02:00 0.50 87 87 PROD3 DRILL PULD P Plug in and download MWD assembly. 02:00 03:00 1.00 87 372 PROD3 DRILL PULD P Continue make up 4 3/4" Welded blade Stabilizer (4.62'), 3 - jnts Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1 - jnt of 4" HWDP (30.67'), 4 3/4" Dailey Hyd Combo Drilling jars (28.82'), and 4 - jnts of 4" HWDP 122.75' .Total BHA = 372.57'. 03:00 03:15 0.25 372 465 PROD3 DRILL OTHR P RIH with 1 stand of DP. Perform Shallow pulse test & break in of Geo-Pilot. 03:15 05:15 2.00 465 4,683 PROD3 DRILL TRIP P TIH with BHA #12, 6 3/4" Geo-Pilot Drilling assembly from 465' - 4683' Fill drill string every 25 stands. Observe ro er hole fill. 05:15 06:00 0.75 4,683 4,683 PROD3 RIGMN SVRG P PJSM with crew. Discuss safety issues and procedure for Slip & Cut. Slip & Cut drilling line. Inspect & service Top Drive. Inspect Brakes on draw works. 06:00 07:45 1.75 4,683 4,683 PROD3 RIGMN SVRG P PJSM, then continue to cut and slip 102' of 1-3/8" drillin line. 07:45 08:15 0.50 4,683 4,683 PROD3 RIGMN SVRG P Service top drive. 08:15 08:30 0.25 4,683 4,770 PROD3 DRILL TRIP P Trip in hole f/ 4683' to 4770' with out pumps on or rotating thru window. Top of window @ 4730'. Bottom of window 4743'. 08:30 12:00 3.50 4,770 5,177 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 4770' to 5177' (407') (3566' TVD) Bit hours= 2.11, Jar (#140-01019) hours= 2.11, ART= 2.11 hrs, WO6= 4-12k, 40-110 rpm, 310-282 gpm @ 2030-1860 psi on bottom and 2000-1800 psi off bottom. Torque = 3-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.01- 9.9 ppg. Avg gas 45 units. P/U = 145-150k, S/O = 110-105k, Rot= 120-125k w/ um s off. 12:00 15:30 3.50 5,177 5,620 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 5177' to 5620' (443') (3539' TVD) Bit hours= 5.0, Jar (#140-01019) hours= 5.0, ART= 2.89 hrs, WO6= 4-12k, 110- 130 rpm, 282-345 gpm @ 1860-2410 psi on bottom and 1800-2400 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-6k ft-Ibs off bottom. ECD= 10.31-10.04 ppg. Avg gas 55 units. P/U = 150k, S/O = 105-100k, Rot= 120k w/ um s off. _~_~ _a._~ ~ ~ _- ~ ®m_ m.~ ,_ _ m ~~ ~. __.~ a. _.~~ _ ~ ______-~ ~ ~ m~~.~ ~ ®.n~®®~n _ _...-..._.~m.~._~~..~_ Time Logs _ _ _ ~ Date From To Dur S. E. De th Phase Code Subcode T 09/26/2006 15:30 17:30 2.00 5,620 5,805 PROD3 DRILL DDRL P _ Drilling 6-3/4" production D lateral f/ 5620' to 5805' (185') (3537' TVD) Bit hours= 6.01, Jar (#140-01019) hours= 6.01, ART= 1.01 hrs, WOB= 6-10k, 130 rpm, 345-336 gpm @ 2450-2370 psi on bottom and 2400-2320 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.16-10.04 ppg. Avg gas 55 units. P/U = 152k, S/O = 100k, Rot= 120k w/ um s off. 17:30 18:00 0.50 5,805 5,613 PROD3 DRILL TRIP T POOH f/ 5805' to 5613' to sidetrack hole. Had a 17 deg dogleg in previous hole. 18:00 19:30 1.50 5,613 5,640 PROD3 DRILL DDRL T Trough hole f/ 5613' to 5640'. Pumping @ 344 gpm w/ 2500 psi. Rotate 130 r m w/ 5-6k ft Ib for ue. 19:30 20:30 1.00 5,640 5,805 PROD3 DRILL DDRL T Drilling 6-3/4" production D lateral f/ 5640' to 5805' (165') (???' TVD) Bit hours= 6.83, Jar (#140-01019) hours= 6.83, ART= .82 hrs, WOB= 6-10k, 130 rpm, 345-336 gpm @ 2450-2370 psi on bottom and 2400-2320 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.16-10.04 ppg. Avg gas 55 units. P/U = 152k, S/O = 100k, Rot= 120k w/ um s off. 20:30 00:00 3.50 5,805 6,015 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 5805' to 6015' (210') (3532' TVD) Bit hours= 9.03, Jar (#140-01019) hours= 9.03, ART= 2.2 hrs, WOB= 6-10k, 100-80 rpm, 344-340 gpm @ 2400-2530 psi on bottom and 2380-2520 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.0 ppg. Max gas 33 units. P/U = 150-152k, S/O = 102k, Rot= 120k w/ pumps off. Pumped a 10.7 ppg, 180 vis sweep while drilling @ 6006'. A 15% estimated increase in cuttings observed the shakers. ~~~ ~ ero~~ ® ~ ~~ .e . ~ .~ .~~~ s ®.. ~~~ m®~~ w _~~.._ ~mm~~r ~ _ t _ I 3 - Time Logs __ - -~- ~ Date From To Dur S~ E Depth Phase Code Subcode T ~~I 09/27/2006 00:00 06:00 6.00 6,015 6,814 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 6015' to 6814' (799') (3524' TVD) Bit hours= 13.08, Jar (#140-01019) hours= 13.08, ART= 4.05 hrs, WOB= 4-8k, 120-110 rpm, 340-330 gpm @ 2420-2660 psi on bottom and 2350-2600 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.0-10.37 ppg. Max gas 60 units. P/U = 155-158k, S/O = 102k, Rot= 120k w/ pumps off. Pumped a 10.7 ppg, 180 vis sweep while drilling @ 6530'. No significant increase in cuttings. A 6' Concretion ending @ 6015', then a 3' concretion was drilled @ 6181' to 6184'. 06:00 12:00. 6.00 6,814 7,495 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 6814' to 7495' (681'} (3518' TVD} Bit hours= 17.38, Jar (#140-01019) hours= 17.38, ART= 4.3 hrs, WO6= 6-8k, 90-130 rpm, 305-336 gpm @ 2660-2340 psi on bottom and 2600-2280 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.24-10.37- ppg. AVG gas 75 units. P/U = 155-165k, S/O = 102-95k, Rot= 120k w/ pumps off. 12:00 18:00 6.00 7,495 8,395 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 7495' to 8395' (900') (3521' TVD) Bit hours= 21.32, Jar (#140-01019) hours= 21.32, ART= 3.94 hrs, WOB= 6-10k, 130 rpm, 330-347 gpm @ 2580-2880 psi on bottom and 2500-2820 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.38 -10.79 ppg. AVG gas 55 units. P/U = 165k, S/O = 95k, Rot= 120k w/ pumps off. Pumped a 30 bbl Hi vis (180) weighted (10.7 ppg) sweep while drilling @ 8344'. A 10-15% increase in cuttings noticed when sweep was back at shakers. A 2' concretion was drilled @ 8116' to 8118'. I=' Time Logs ~ _ __ - - -- Date From To Dur S. E. De th Phase Code Subcode T C~ICI 09/27/2006 18:00 00:00 6.00 8,395 9,102 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f! 8395' to 9102' (707') (3519' TVD) Bit hours= 26.04, Jar (#140-01019) hours= 26.04, ART= 4.72 hrs, WO6= 8-10k, 130 rpm, 340-348 gpm @ 2840-3200 psi on bottom and 2790-3170 psi off bottom. Torque = 6-8k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.79-10:93 ppg. AVG gas 55 units. P/U = 165-167k, S/O = 95-92k, Rot= 95-125k w/ pumps off. Pumped a 30 bbl Hi vis (180) weighted (10.7 ppg) sweep while drilling @ 8999'. A 15% increase in cuttings noticed when sweep was back at shakers. A 8' Concretion was drilled f/ 8712' to 8720', then a 18' Concretion was drilled f/ 8721' to 8739', then a 12' Concretion was drilled f/ 8991' to 9003'. 09/28/2006 00:00 03:30 3.50 9,102 9,490 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9102' to 9490' (388') (3524.28' TVD) Bit hours= 28.54, Jar (#140-01019) hours= 28.54, ART= 2.5 hrs, WO6= 6-10k, 130 rpm, 340-348 gpm @ 3150-3250 psi on bottom and 3050-3170 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.8-11.54 ppg. Max gas 183 units. P/U = 165-170k, S/O = 92-88k, Rot= 125-120k w/ pumps off. Pumped a 30 bbl Hi vis (200) weighted (10.8 ppg) sweep while drilling @ 9400' (3523' TVD). An approximate 25% increase in cuttings noticed when sweep was back at shakers. A 3' Concretion was drilled f/ 9176' to 9179', then a 11' Concretion was drilled f/ 9293' to 9304'. ~~..~ ~ ..._ ~ . e....®. m...~ _. ~®e~._ ~.-~m®®~ e m~® ~~~~ __ __ -~ ~~ ~~~ ___ .. a e...... ~ _ ®~ vs .~~~_~.~.~® _..._ ~ .. ~ , 1 . _.___..... .__..,,.,.... .._........ ,, ._,__ ....... ......... _._..,,,,_„W,... ,........_. _..._. ...___..~ .._._.....~_~._,. ems........_ -...-.. ,._m..~._....... -.._. .. s.~~., .,,,m®,.m ~.._.._ Time Logs _ Date From To Dur S: E. De th Phase Code Subcode T UPI 09/28/2006 _ 03:30 04:45 1.25 9,490 9,599 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9490' to 9599' (109') (3520' TVD) Bit hours= 29.12, Jar (#140-01019) hours= 29.12, ART= .58 hrs, WO6= 6-10k, 130 rpm, 340-348 gpm @ 3150-3250 psi on bottom and 3050-3170 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.8-11.54 ppg. Max gas 183 units. P/U = 165-170k, S/O = 92-88k, Rot= 125-120k w/ pumps off. A 4' concretion was drilled f/ 9555' to 9559'. When the Concretion @ 9555' was drilled, it caused an 11 deg dogleg in the well (9 deg/100' build and 5 deg turn ri ht . 04:45 05:00 0.25 9,599 9,466 PROD3 DRILL TRIP T Surrey check shot @ 9564'. POOH f/ 9599' to 9466' for sidetrack because of an 11.01 deg dogleg in hole (9 deg per hundred build and 5 de turn ri ht . 05:00 06:30 1.50 9,466 9,490 PROD3 DRILL DDRL T Trough hole f/ 9466' to 9490'. Pumping 340 gpm w/ 3100 psi. Rotating 130 r m w/ 6500 ft Ib for ue. 06:30 08:30 2.00 9,490 9,599 PROD3 DRILL DDRL T Drilling 6-3/4" production D lateral f/ 9490' to 9599' (109') (3528' TVD) Bit hours= 30.98, Jar (#140-01019) hours= 30.98, ART= 1.86 hrs, WOB= 6-8k, 110 rpm, 340 gpm @ 3200 psi on bottom and 3120 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.33 ppg. Max gas 183 units. P/U = 170k, S/O = 85k, Rot= 120k w/ um s off. 08:30 12:00 3.50 9,599 10,076 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9599' to 10076' (477') (3530' TVD) Bit hours= 33.46, Jar (#140-01019) hours= 33.46, ART= 2.48 hrs, WOB= 4-8k, 130 rpm, 340-348 gpm @ 3330-3480 psi on bottom and 3280-3400 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.43-10.96 ppg. Avg gas 60 units. P/U = 170-175k, S/O = 85-80k, Rot= 120-118k w/ um s off. ..ne ~~ ® .m.~ ~ em _ v..m.~ ..~®e~ ~ ~ __....... ~..~~ __...~~.m- ~~_. ~-_ Time Logs _ ~ ~I-- Oate From Tn Dur S ~7~ F nenth PhaGe CndP Suhnnrie T l~~l 09/28/2006 12:00 18:00 6.00 10,076 10,822 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 10076' to 10822' (746') (3516' TVD) Bit hours= 37.77, Jar (#140-01019) hours= 37.77, ART= 4.31 hrs, WO6= 4-10k, 80-130 rpm, 293-345 gpm @ 2690-3670 psi on bottom and 2600-3560 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 7k ft-Ibs off bottom. ECD= 10.6-11.2 ppg. Avg gas 75 units. P/U = 175-180k, S/O = 80-75k, Rot= 120-118k w/ pumps off. Pumped a 20 bbl Hi Weight, Hi vis sweep while drilling @ 10645'. Slight increase in cuttin s noted shakers. 18:00 00:00 6.00 10,822 11,698 PROD3 DRILL DDRL P 09/29/2006 00:00 03:00 3.00 11,698 12,095 PROD3 DRILL bDRL P Drilling 6-3/4" production D lateral f/ 11698' to 12095' (397') (3506' TVD) Bit hours= 42.74, Jar (#140-01019) hours= 42.74, ART= 1.63 hrs, WOB= 8-12k, 90 rpm, 280-290 gpm @ 2640-2900 psi on bottom and 2620-2590 psi off bottom. Torque = 9-10k ft-Ibs on botttom and 8-9k ft-tbs off bottom. ECD= 11.1-11.50 ppg. Max gas 230 units. P/U = 195-198k, S/O = 75k, Rot= 120k w/ pumps off. Pumped a 20 bbl Hi Weight (10.8 ppg), Hi vis (200) sweep while drilling 12050'. 03:00 04:45 1.75 12,095 11,741 PROD3 DRILL CIRC P Pump 20 bbls hi vis (200), hi wt (10.8 ppg) to inside casing while roating 130 rpm w/ 9k ft Ib torque. Pumping 337 gpm w! 3700 psi. Recip pipe f/ 12095' to 12000' until sweep inside of casing, then continue backreaming to 11741', till sweep out of hole. Circ total of 712 bbls. 04:45 05:30 0.75 11,741 12,095 PROD3 DRILL REAM P Ream from 11741' back to bottom @ 12095'. No down weight without rotation. Pump 280 gpm w/ 2575 psi. Rotate 100 rpm w/ 8k ft Ib torque. ECD's 11.12 ppg. Pumped a total of 149 bbls while reaming back to bottom. 05:30 07:45 2.25 12,095 10,650 PROD3 DRILL TRIP P POOH UD single 4" dp, continue POOH 15 stands to 10650', hole taking proper displacement. No problems. Record PU and SO wt's eve 5 stands. 07:45 08:00 0.25 10,650 10,650 PROD3 DRILL OWFF P Monitor well. Clean rig floor. Hole takin a small amount of fluid. 08:00 08:15 0.25 10,650 10,650 PROD3 DRILL CIRC P Pump dry job. 08:15 09:15 1.00 10,650 10,200 PROD3 DRILL TRIP P POOH f/ 10650' to 10200'. Tight spot 10200'. Work i e. ~~ ®a.. . ~ - ~ A.~ _ _ ®.m ®___ i...® __ ~ m. ®e ~ ,..~- ._, __ _~ _- .. ~n__._ _..__.__ _.....~ ...~ ~._-_v ~ .... ~.~..___.____... ~ m mm..~~___~.~ _.me~~-__ mm~ ~~ ~ ®.a~_ ~..~~ ~~~ - ~.. Time Logs _ "Date From To Dur S. ~ E. De th Phase Code Subcode T ~1f1 09/29/2006 09:15 _ 10:30 1.25 10,200 9,654 PROD3 DRILL REAM P Backream out of hole f/ 10200' to 9654'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's eve 5 stands. 10:30 12:00 1.50 9,654 8,560 PROD3 DRILL REAM P Backream out of hole every other stand f/ 9654' to 8560'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's every 5 stands. 12:00 16:30 4.50 8,560 4,965 PROD3 DRILL REAM P Backream out of hole every other stand f/ 8560' to 4965'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's every 5 stands. 16:30 16:45 0.25 4,965 4,683 PROD3 DRILL TRIP P Pull 3 stands f/ 4965' to 4683'. No pumping or rotation while pulling these stands throu h window. 16:45 17:00 0.25 4,683 4,683 PROD3 DRILL OWFF P Monitor well. Static. 17:00 18:00 1.00 4,683 4,683 PROD3 DRILL CIRC P Pump 30 bbl hi vis (200), hi wt (10.8 ppg) sweep and circulate 3 bottom's up (4250 strokes/ 427 bbls). Pumped @ 345 gpm w/ 2750 psi. Rotate 120 rpm w! 4-5 k ft/Ib torque. Observed hole losses of 8b h. 18:00 19:15 1.25 4,683 4,683 PROD3 RIGMN SVRG P Service rig and top drive. Crown and blocks serviced. Measure windwall pin ockets for wall b derrick board. 19:15 23:45 4.50 4,683 10,309 PROD3 DRILL TRIP P Trip in hole f/ 4683' to 10309'. Record PU and SO wt's every 5 stands. Fill i e after 25 stands. 23:45 00:00 0.25 10,309 10,402 PROD3 DRILL REAM P Start reaming in the hole f/ 10309'. No Down weight. Ream to 10402'. Pumping 85 gpm w/ 600 psi. Rotate 50 rpm w/ 7-8k ft Ib torque. Running speed 20-30 ft/min. Record PU and SO wt's eve 5 stands. 09/30/2006 00:00 04:00 4.00 10,402 12,095 PROD3 DRILL REAM P Continue reaming in the hole f/ 10402' to 12095'. No Down weight. Ream to 10402'. Pumping 85 gpm w/ 600 psi. Rotate 50 rpm w/ 7-8k ft Ib torque. Running speed 20-30 ft/min. Record PU and SO wt's eve 5 stands. 04:00 05:30 1.50 12,095 12,095 PROD3 DRILL CIRC P Pump 23 bbl Hi vis (140), hi wt (10.8 ppg) sweep. Circ total of 7250 strokes (725 bbls). Held PJSM w/ truck drivers and crew prior to displacement to SFOBM. Pump @ 340 gpm w/ 4000 si. ECD's 12.1. 05:30 05:45 0.25 12,095 12,095 PROD3 DRILL OWFF P Monitor well. OK. Take SPR's w/ 8.8 ppg OBM in hole @ 12095' (3501' TVD . I `_`" L._.. Time Los 9 Date From To Dur S. Dl1 E. De th Phase Code Subcode T _ 09/30/2006 05:45 06:45 1.00 12,095 12,095 PROD3 DRILL CiRC P _ Displace "D" lateral open hole from 8.8 ppb OBM to 8.7 ppg SFOBM. Pump 340 gpm w/ 3800-3600 psi. Rotate 130 rpm w/ 7-9k ft Ib's torque. Pumped 345 bbls SFOBM, follow w/ 24 bbls dry job, chase w/ 6 bbls OBM. 06:45 07:00 0.25 12,095 12,065 PROD3 DRILL PULD P Break off single 4" HWDP. UD jt. Drop 2.32" rabbit w/ wireline 100' lus. 07:00 10:15 3.25 12,065 4,700 PROD3 DRILL TRIP P POOH on elevators f/ 12065' to 4700' to run 4-1/2" PLOP and Drop liner. Record PU and SO wt's every 5 stands in o en hole. Above window. 10:15 10:30 0.25 4,700 4,700 PROD3 DRILL OWFF P Monitor well. Static. 10:30 12:15 1.75 4,700 372 PROD3 DRILL TRIP P Continue POOH f/ 4700' to BHA @ 372'. Record PU and SO wt's every 10 stands in cased hole. 12:15 14:00 1.75 372 92 PROD3 DRILL PULD P UD HWDP, jars and flex collars to i e shed. 14:00 14:30 0.50 92 92 PROD3 DRILL OTHR P Sperry Sun download MWD tools. Clean and clear ri floor. 14:30 15:30 1.00 92 0 PROD3 DRILL PULD P UD MWD tools, break bit. UD Sperry Sun GeoPilot. 15:30 16:15 0.75 0 0 COMPZ CASIN( RURD P RU casing running tools while laying down subs f/ BHA # 12. 16:15 16:30 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" Plop and drop liner f/ "D" lateral 16:30 18:00 1.50 0 1,285 COMPZ CASIN( RNCS P Running 4-1/2" Plop and drop slotted and blank liner f/ "D" lateral to 1285'. Record PU and SO wt's every 20 jts in casin . 18:00 23:00 5.00 1,285 7,151 COMPZ CASIN( RNCS P Continue running 4-1/2" Plop and drop slotted and blank liner f/ "D" lateral f/ 1285' to 7151'. Record PU and SO wt's every 20 jts in casing, every 10 jts in open hole. With all the liner in the hole: PU wt 122k, SO wt 93k. Rot wt 105k. Rotating 25 rpm w/ 4-5k ft Ib torque, PU wt= 115k, SO wt 103k. 23:00 00:00 1.00 7,151 8,185 COMPZ CASIN< RUNL P Run 4-1/2" slotted/blank liner as a Plop and drop in the "D" lateral. Run liner on 4" DP f/ 7151' to 8185'. Run 3 stands slick, then start w/ 4" dp w/ super sliders. Record PU and SO wt's eve 5 stands in o en hole. 10/01/2006 00:00 02:30 2.50 8,185 12,081 COMPZ CASIN( RUNL P Run 4-1/2" slotted/blank liner as a Plop and drop in the "D" lateral. Run liner on 4" DP f/ 8185' to 12081'. Run 31 stands 4" dp w/ super sliders, 4 stands 4" HWDP, then 15 stands of Hybrids ((2) 5" DC's and one 4" HWDP). Record PU and SO wt's every 5 stands in o en hole. ®®~ ~ ~_.._~_ ~__~v. w.~ ~~.~ ~~. ;_- _._~m~ ~ s ..eem~ _._._ e.®.®.~.. -~ ~. ~~s e~®~. ®......a.~~~wr. Time Los _ __ g Date From To Dur S. E_ De th Phase Ccde Subcode T ~ I 10/01/2006 02:30 02:45 0.25 12,081 12,092 COMPZ CASIN( OTHR _ P _ __ Rotate liner @ 12081'. Without rotating: PU wt 215k, SO wt 93k. Rotating wt 155k. Rotate @ 25 rpm w/ 8k ft Ibs torque. While rotating: PU wt 180k, SO wt 135k. 02:45 03:00 0.25 12,092 12,092 COMPZ CASIN( OTHR P PU/MU single 4" HWDP, rotate and tag bottom @ 12095', PU and L/D single. Drop 29/32" ball. Make up top drive. 03:00 03:45 0.75 12,092 12,081 COMPZ CASIN( CIRC P Rotate and PU string to set shoe @ 12081.34'. Pump ball down @ 3bpm w/ 500 psi f/ 26 bbls, then slow to 2 bpm w/ 320 psi till ball on seat (411 strokes). Pressure to 3000 psi, to release liner, set down to 110k (30k), PU and string wt was 170k (loss of 45k liner weight). PU 10', pressure to 3875 si to blow ball seat. 03:45 04:15 0.50 4,929 4,730 COMPZ CASIN( RUNL P POOH wet 2 stands of Hybrids. Make up top drive, pull 3rd stand out. Strap stand in. 04:15 04:45 0.50 4,730 4,730 COMPZ CASIN( CIRC P Circ and rotate to clean key slot in whipstock. Pump 80 spm w/ 1525 psi. Rotate 40 rpm w/ 4k ft Ibs torque. Pump a total of 197 bbls. 8.6 ppg mud wt. 04:45 05:00 0.25 4,730 4,730 COMPZ CASIN( RUNL P Monitor well. Static. Pump dry job. 05:00 06:00 1.00 4,730 2,996 COMPZ CASIN( RUNL P Blow down top drive. POOH f/ 4730' to 2996' 06:00 08:00 2.00 2,996 0 COMPZ CASIN( RUNL P Continue POOH w/ liner running tools f/ "D" lateral. 08:00 08:30 0.50 0 0 COMPZ CASIN( OTHR P Break and UD Baker tools to pipe shed. 08:30 09:15 0.75 0 0 C.OMPZ CASIN( OTHR P Clear and clean rig floor. UD casing runnin tools, subs, ets. 09:15 09:30 0.25 0 0 COMPZ FISH SFTY P PJSM on picking up Baker Whipstock retieval hook assembl . 09:30 10:00 0.50 0 59 COMPZ FISH PULD P MU BHA to retieve whipstock. MU hook to a single 3-1/2" HWDP, bumper 'ars, oil 'ars, x-o. 10:00 10:30 0.50 59 425 COMPZ FISH TRIP P PU 3 stands hybrids as part of BHA and a sin le stand of 4" su er sliders. 10:30 10:45 0.25 425 425 COMPZ RIGMN SFTY P PJSM on cutting drilling line. 10:45 12:15 1.50 425 425 COMPZ RIGMN SVRG P Slip and cut 126' of 1-3/8" drilling line. 12:15 15:00 2.75 425 4,736 COMPZ FISH TRIP P Continue RIH w/ Baker whipstock retrieval assembly. Ran 35 super slider stands, 4 stands HWDP and 8 stands H brids, then sin le HWDP. 15:00 15:30 0.50 4,736 4,736 COMPZ FISH CIRC P Break circ @ 3bpm w/ 400 psi. PU wt 170k, SO wt 135k. 15:30 15:45 0.25 4,736 4,736 COMPZ FISH FISH P Found slot and hooked @ 4735.5'. Pulled 90k over to 260k. m®m~ ~ ~_~~ ~ ~ ~g Y! ~ rv~.~ ~.}9 Eb .J Time Logs ___ Date .From To Dur S. E. Depth Phase Code Subcode T I 10/01/2006 15:45 16:00 0.25 4,736 4,726 COMPZ FISH TRIP P _ PU and L/D single HWDP. 16:00 16:45 0.75 4,726 4,660 COMPZ FISH CIRC P Pull stand up and circ @ 4660'. Circ bottom's up @ 8 bpm w/ 2140 psi. Pum 200 bbls. 16:45 17:00 0.25 4,660 4,660 COMPZ FISH OTHR P Monitor well. Static. 17:00 17:30 0.50 4,660 4,660 COMPZ FISH CIRC P Pump 25 bbls dry job, drop 2.32" rabbit. Blow down to drive. 17:30 18:00 0.50 4,660 3,370 COMPZ FISH TRIP P POOH w/ whipstock assembly f/ 4660' to 3370' 18:00 21:00 3.00 3,370 0 COMPZ FISH TRIP P POOH w/ whipstock retieval BHA and whipstock assembly. 15 bbls over talc on tri out. 21:00 21:30 0.50 0 0 COMPZ FISH PULD P UD Baker Fishing assembly (Hooking assembl 21:30 22:30 1.00 107 0 COMPZ FISH PULD P UD Whipstock assembly: Whipstock, circ sub, anchor, debris sub, 2 jts of 3-1/2" HWDP, safety shear sub, unloader sub, 15' 3-1/2" pup, no go and seals. 22:30 23:00 0.50 0 0 COMPZ FISH PULD P Cleaning rig floor and UD Baker tools. Hole takin 6.5 b h. 23:00 23:00 0.00 0 0 COMPZ CASIN( RURD P RU casing tools to run 4-1/2" Hook Han er. 23:00 23:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on PU Hook Hanger assembly f/ "D" lateral 23:15 00:00 0.75 0 30 COMPZ CASIN( PUTB P PU/MU 4-1/2" Slot/blank hook hanger assembl 10/02/2006 00:00 02:30 2.50 30 266 COMPZ CASIN( OTHR P MU Sperry Sun MWD up to Baker hook han er, orient same. 02:30 02:45 0.25 266 266 COMPZ CASIN( DHEQ P Shallow test MWD w/ 100 gpm w/ 490 si. 02:45 05:45 3.00 266 4,875 COMPZ CASIN( RUNL P RIH w/hook hanger on 4" dp. Use 35 stands w/ super sliders, 4 stands 4" HWDP, then hybrids ((2) 5" DC's w/ one 4" HWDP). Top of window is @ 4730', Bottom of window @ 4743'. Tagged up on no go (x-o bushing) in "B" lateral 4875'. 05:45 07:00 1.25 4,875 4,875 COMPZ CASIN( RUNL P On fourth attempt to exit window w/ 4-1/2" bent joint w/ mule shoe, we did exit window. Run to 4875'. 07:00 07:30 0.50 4,875 4,963 COMPZ CASIN( CIRC P Continue RIH w/ hook hanger assembly f/ 4875' to 4963'. Circulate 100 gpm w/ 890 psi. Orient hook hanger to hook window. PU wt 170k, SO wt 140k. t-~ ~ o. E Time Logs Date From To Dur S E. De th Phase Code Subcode T 10/02/2006 07:30 08:00 0.50 4,963 4,985 COMPZ CASIN( OTHR P Slack off and hook window, unhook, rotate 180 deg to pass through w! hook hanger, slack off and tag no go (crossover bushing in Plop and drop assembly @ 4995'), PU above window, orient to hook window (oriented to 17 Left, when hooked went to 3 left), set down 30k on hook. PU wt 170k, SO wt 147k. 08:00 08:45 0.75 4,985 4,985 COMPZ CASIN( OTHR P Drop 29/32" ball, circ down to seat w/ 125 gpm w/ 1050 psi for 250 stokes, then to 85 gpm till on seat @ 40.46 bbls pumped. Pressure to 1450 psi, hold, continue to increase pressure to 2800 psi (opening ECP, dropping to 1570 psi. Increase pressure to 2800 psi w! 3 strokes (.301 bbls). PU to 170k. 08:45 09:00 0.25 4,718 4,668 COMPZ CASIN( RUNL P POOH and stand back a stand.Pump d 'ob. Blow down to drive. 09:00 11:45 2.75 4,668 0 COMPZ CASIN( RUNL P POOH w/ Baker Hook Hanger running tools. 11:45 13:15 1.50 0 0 COMPZ CASIN( OTHR P Break and UD Baker running tools. 13:15 14:00 0.75 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor while laying down Baker tools and subs. 14:00 14:30 .0.50 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" LEM for "D" lateral. 14:30 16:00 1.50 0 204 COMPZ CASIN( PUTS P PU/MU LEM assembly f/ "D" lateral to 204'. 16:00 18:00 2.00 204 3,600 COMPZ CASIN( RUNL P RIH w/ LEM f/ 204' to 3600' on 4" drill strin . 18:00 19:15 1.25 3,600 4,866 COMPZ CASIN( RUNL P Continue RIH w/ LEM on 4" drill string f/ 3600' to 4866'. LEM sna ed in 19:15 19:30 0.25 4,866 4,866 COMPZ CASIN( OTHR P Set down 30k, Pull to 230k and snap out. RIH and latch in w/ 30k on LEM. PU to 180k. Drop 1-3/4" ball. PU wt 192k, SO wt 125k. 19:30 19:45 0.25 4,866 4,866 COMPZ CASIN( CIRC P Circ ball to seat. Pump 3 bpm w/ 400 psi ,then to 2 bpm w/ 260 psi. Ball on seat 32.7 bbls. 19:45 20:30 0.75 4,866 4,866 COMPZ CASIN( OTHR P Pressure to 2500 psi, hold, then increase to 4000 psi to neutralize pusher tool, slack off to 115k to release HRD setting tool. Break off top drive. Test annulus to 1000 psi f/ 5 min., chart test. 20:30 20:45 0.25 4,866 4,574 COMPZ CASIN( RUNL P After LEM set and released: PU wt 170k, SO wt 140k. POOH to 4574' 20:45 21:00 0.25 4,574 4,574 COMPZ CASIN( CIRC P Pump dry job, blow down top drive. 21:00 23:15 2.25 4,574 0 COMPZ CASIN( RUNL P POOH w/ LEM running tools f/ 4574' to surface. 23:15 00:00 0.75 0 0 COMPZ CASIN( OTHR P UD Baker LEM running tools. -5. ~ j Time Logs Date From To Dur S. E. De th Phase Code Subcode T_ _ 10/03/2006 00:00 00:45 0.75 0 0 COMPZ CASIN( OTHR P UD Baker LEM running tools. 00:45 01:15 0.50 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. Monitor well via tri tank and hole fill um . 01:15 01:45 0.50 0 0 COMPZ RPCOh OTHR P Pull Vetco/Gray wear bushing. Hole takin 2 b h. 01:45 02:15 0.50 0 0 COMPZ RPCOh RURD P PJSM, Rig up to run 4-1/2" completion, GBR casing crew and e ui ment. 02:15 02:30 0.25 0 0 COMPZ RPCOti SFTY P PJSM on running 4-1/2" 12.6 ppf L-80 IBT-mod completion. GBR casing crew, Baker completion supervisor, tour usher and ri su ervisor. 02:30 03:15 0.75 0 65 COMPZ RPCOh RCST P PU Baker 4-3/4" seal assembly, Made up 1 jt 4-1/2" 12.6 ppg L-80 IBT-mod tubing, then 4-1/2" pup on CMU did not make u correct. 03:15 04:45 1.50 65 65 COMPZ RPCOh PULD T Break out CMU assembly w/ pup, break and UD bottom pup, PU/MU another 4-1/2" 12.6 ppf L-80 IBT-mod pup which did not make up correct again. UD 1st joint and replace w/ jt # 150 (same length 31.07'). Make up pup jt 6.17', then make up CMU. Torque tubing to 2500 ft Ib torque to middle makeup mark. Probably overtorqued collar of 1st jt. Collar was hot. Pin end of pup jt screwed in ast make u mark. 04:45 06:00 1.25 65 600 COMPZ RPCOh RCST P Continue MU 4-1/2" completion. Checking torque and MU. 2500 ft Ib seems to be optimum torque on 4-1/2" IBT-M. Check make up mark on every connection (4-3/8" MU thread loss on 't . 06:00 09:45 3.75 600 4,713 COMPZ RPCOh RCST P Continue MU 4-1/2" completion. Run f/ 600' to 4672' (top of LEM ZXP packer (LEM Tally)). Locate @ 4683.66' (11.01' inside ZXP (LEM Tally)), Tubing detail =4686.01'. Checking torque and MU. 2500 ft Ib seems to be optimum torque on 4-1/2" IBT-M (4-3/8" thread loss). Note: Tagged 2.35' deeper by tubing tall numbers. 09:45 10:30 0.75 4,713 4,627 COMPZ RPCOh HOSO P UD 3 joints (149, 148, 147), leaving jt # 146 in hole. PU 7.80' 4-1/2" 12.6 ppf L-80 IBT-mod tubing pup drifted to 3.91". Rabbit Vetco Gray hanger and u to 3.885". 10:30 10:45 0.25 4,627 4,635 COMPZ RPCOh HOSO P MU 7.80' 4-1/2" 12.6 ppf L-80 IBT-mod tubing pup drifted to 3.91". MU jt # 147. 10:45 11:15 0.50 4,635 4,708 COMPZ RPCOh HOSO P MU Vetco Gray hanger w/ pup, then landing joint. RIH and land hanger. Install BPV, RILDS. 1 ~ .~ t I Time Logs _ _ Date From To Dur S. ~ E. De th Phase Code Subcode T ~4I 10/03/2006 11:15 12:00 0.75 0 0 COMPZ DRILL OTHR P Clean and clear rig floor, laying down casing equipment, subs and Baker tools. 12:00 12:30 0.50 0 0 COMPZ DRILL RURD P RU to laydown 4" drill string f/derrick, usin mousehole. 12:30 12:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down 4" drill string f/ derrick, usnin mousehole in stack. 12:45 18:00 5.25 0 0 COMPZ DRILL PULD P Lay down 4". Layed down 15 stands of hybrids ((2) 5" DC's w/ a single 4" HWDP), 4 stands 4" HWDP, then 30 stands of slick drill i e. 18:00 00:00 6.00 0 0 COMPZ DRILL PULD P Lay down 37 stands of 4" slick drill pipe. Note: 15 slick stands + 40 stands w/ su er sliders left to be la ed down. 10/04/2006 00:00 08:30 8.50 0 0 COMPZ DRILL PULD P Lay down 15 stands 4" slick dp + 40 stands w/ su er sliders . 08:30 10:00 1.50 0 0 COMPZ DRILL PULD P Lay down thread protectors. Clear and clean rig floor. Move 11 stands 5" DP in derrick f/ off driller's side to driller's side while cleaning drip pan under rig floor. Total of 21 stands 5" dp in derrick + 2 stands 5" HWDP + stand w/ "ars. 10:00 10:45 0.75 0 0 COMPZ DRILL PULD P UD Mousehole, subs, lifting subs, elevators, test plugs, etc. not needed on ri an more. 10:45 11:00 0.25 0 0 COMPZ DRILL OTHR P Blow down all surface equipment and um s. 11:00 15:00 4.00 0 0 COMPZ RPCOh NUND P Nipple down 13-5/8" BOPE. Cleaning its. 15:00 15:45 0.75 0 COMPZ RPCOti NUND P NU Vetco Gray tree. Install actuator on horizontal tree. 15:45 16:00 0.25 0 0 COMPZ RPCOh OTHR P Rig up to test tree. 16:00 16:15 0.25 0 0 COMPZ RPCOh DHEQ P Test tree to 5000 psi. Chart test f/ 10 minutes. 16:15 16:45 0.50 0 0 COMPZ RPCOh SFTY P PJSM w/ little Red on freeze protection/ displacement to diesel. Test lines to 3000 si. 16:45 19:30 2.75 0 0 COMPZ RPCOti FRZP P Freeze protect/ displace well by pumping down 7-5/8" x 4-1/2" annulus. CMU open @ 4631'. Taking returns from tubing to pits. Monitor rates, pressures and return volume to pits. 11 bbls to fill well. 16 bbls pumped to get returns to pits. Pumped a total of 217 bbls diesel. Calc volume surface to surface is 192 bbls. Did not loose over a bbl on displacement. start @ 1 bpm w/ 200 psi, when pumping @ 2.5 bpm appeared to be losing 1/3 bbl. Pumped @ 2bpm till diesel @ CMU w/ 600 psi, then increase rate to keep about 500 si. Final rate 4 b m w/ 475 si. ,~ ~ ~ a.m~.. sem~~~ e .... ~~ ~s~Re~._ __ _~ ~ ®..®em ® ~~.,.- .e ~~~~ ~ ~..__._.~ ~ _ __ .~ ~..a ~ ~ _, ~-~c~~ l -- Time Logs --~ _ ---_ - - - Date From To Dur S. ~ F. Depth Phase Code Subcode T ~m _ 10/04/2006 19:30 20:00 0.50 0 0 COMPZ RPCOh FRZP P Rig down and blow down freeze rotection a ui ment and hoses. 20:00 20:45 0.75 0 COMPZ RPCOI~ NUND P Cleaning pits, Remove double valve on inner annulus, install companion flange and guage. Remove fittings on Actuated valve, install guages. Tubing pressure 200 psi. 7-5/8" x 4-1/2" ann pressure= 225 psi. 10-3/4" x 7-5/8" ressure = 175 si. 20:45 00:00 3.25 0 0 COMPZ RPCOh OTHR P PU lubricator, Install BPV w/ Vetco/Gray. Secure well. Continue cleaning pits. Blow down steam to sub module. R/D mud lines, water lines and steam lines between modules. Cleaning pits, preparing to clean cellar. Tubing pressure 200 psi. 7-5/8" x 4-1/2" ann pressure= 225 psi. 10-3/4" x 7-5/8" ressure = 175 si. .en m.... __ ____, ..~. ~_ - _ ~ ..__. . _ n ~e~ m m~ ._ _ ~ _~____ ~_ _..~ ~c s r ~_ .~ . _ ___ ~__ . ~ ~ w ~ d____ _ .. r ~ ®. • c: 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-102 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey: Projected Survey 9,155.78' MD 0.00' MD (if applicable) 11,025.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 V Date ~ ~~~/ ~.0~i b Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ac1~ - J(~ • • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-102PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey: Projected Survey 40.30' MD 0.00' MD (if applicable) 8,159.00' M D PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.AllenCHALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorpa~g/'e, AK 99518 Date [ NP/ ~ (s Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ac~~~-icy • • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-102PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey: Projected Survey: 7, 655.58' M D 0.00' MD (if applicable) 8,401.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ r/ ~~_ Signed Please call me of 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~~ ~~~ • • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-102PB3 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey: Projected Survey 7,561.99' MD 0.00' MD (if applicable) 9,846.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~t/ ~4~ ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~- l~~ • FELL. L®G T~2.ai~Sid'IITTAL~ • Toe State of Alaska November 6, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska - RE: MV~~ Formation Evaluation Data: 1 J-102, PB 1, PB2, PB3, L 1, L2, L2 PB 1 & L2 PB2 AK-MW-45 ~ 9176 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23317-00, -?0, -71, -72, -60, -61, -73 & -74 PLEASE ACICiVOWI,EDGE RECEIPT BY SIGrI'~iG :~~D RETL!`RNING a COPY' OF THE TRY;rSYIITT:~L LETTER TO THE ATTErTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Bivd. Anchorage, Alaska 99518 Date: /~ ~~ ~~ ~~~ t ~ ~ Ana, `~~ ~ , ~~a , ~~~ J ° I0~ ~ ~ ~~ ~ ~ ~~~~ t .~ ~- ~.~ `~, , Signed: ,~' ~:~ v7J~' ~' ~ alJ /~!a /C~ ~i~ t~.~ ' l 1 ~ ~ 1-l ~ i ~ 09/15/06 • Sehtumf~erger ~~ ~ ~ ~~ N0.3959 Schlumberger -DCS S~~ ~ 2525 Gambell Street, Suite 400 ~ 2C~E Company: Alaska Oil 8~ Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ~ ~`~'' ~S ~GiiS. ~ITF,t1'~=~~>j 333 West 7th Ave, Suite 100 ~w 1 ~~'~ Anchorage, AK 99501 ~a~ ~ ~ 1 b Field: Kuparuk Well Job # Log Description Date BL Color CD 2A-18 11213804 LDL 09/09/06 1 1A-20 11213802 PROD PROFILE W/DEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1L-28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1L-10 1142164 INJECTION PROFILE 09/09/06 1 1J-102 11421625 USIT 09/11/06 ~' 2E-05 N/A INJECTION PROFILE 09/07/06 1 2E-05 11216326 SBHP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1 J-102 Subject: 1J-102 From: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com> Date: Fri, 08 Sep 2006 14:39:54 -0800 To: Thomas Maunder <tom maunder c~,adnli~~.state.ak.us-> Tom, ~~~ "~0,~ The details of the sidetrack are as follows: • Well: 1 J-102 • Rig: Doyon 15 • Date: 9/8/06 • Time: 1400 hrs • Last Casing: 5,920 • MD of abandoned section: 9,200' - 9,846' We exited the formation twice due to geologic uncertainty. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. Please see the enclosed PDF and let me know if you concur with my nomenclature. Thanks. «1J-102 as of 090806.PDF» Pat Reilly ConocoPhillips Alaska Drilling & Wetls (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly@conocophillips.com «Patrick.J.Reilly@conocophillips.com.vcf» '' 'Content-Description: 1J-102 as of 090806.PDF '1J-102 as of 090806.PDF'' Content-Type: application/octet-stream 'Content-Encoding: base64 1 of 1 9/12/2006 9:16 AM a ~' .r ~ ~G f ~- ~ U ~ ~f r ~n ~/ 6 ,~ ~ ~~ ~ r a _~ 0 v 6 - R~, j ~ ~, 1` o ,s~ ! N J ~ "" p~., r G ~ ~~ . ,--- _._...a ~; r 0 G u -~ ~~ o -- 3 -1 _~ -~, v n ,: f- ~~ r- ~. 3- 0 u 0 y~ V_ N w+ ss r' -~ d_ 00 Ui -C~ cn 0 a W L1 d ro ca `'~ f 0 ~' a s 0 6" 1J-102 A Lateral Geological Sidetrack #2 Subject: 1J-'102 A Lateral Geological Sidetzack #2 From: "Reilly; Patrick J" <Patrick.f.Reilly c~conocophillips.coi~1> Date: Thu, 07 Sep 2006 16:3~1:tk0 -0800 To: Thomas Maunder - tom_maunder@admil~state.~k.us=~~ ~~-~~,v Tom, The details of the sidetrack are as follows: • Well: 1 J-102 • Rig: Doyon 15 • Date: 9/7/06 • Time: 0800 hrs • Last Casing: 5,920 • MD of abandoned section: 7,612' - 8,401' We are abandoning a crooked hole section that was caused by a malfunctioning rotary steerable tool. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. I plan on calling tomorrow to make sure we agree on the nomenclature for the abandoned section. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reil ly@conocophillips.com «Patrick.J.Reilly@conocophillips.com.vcf» 1 of 1 9/12/2006 9:15 AM Re: 1J-102 A Lateral Geological Sidetrack Subject: Re: 1J-102 A Lateral Geological~detrack From: Thoi7las Maunder <tom maunder(~i::adinin.state.ak.us> Datc: Tue, U~ Sep 2.006 13:2C~:U4 -)S00 ~I'o: "Reilly, Patrick J" <Patrick.J.Reillv~~lconocoplullips.cort~== Pat, Thanks for the information. Your plan is appropriate. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 9/5/2006 12:46 PM: ', Tom, The details of the sidetrack are as follows: • Well: 1 J-102 • Rig: Doyon 15 • Date: 9/5/06 • Time: 0115 hrs • Last Casing: 5,920 • MD of abandoned section: 7,710' - 8,159' • a~-~G~ We exited the top of the formation due to geologic uncertainty. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. If you need any additional information please contact me. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. ReillyC~conocophillips. com «Patrick.J.Reilly(c~r,conocophillips.com.vcf» 1 of l 9/5/2006 l :20 PM ~;~ - ,~` ~ ~, ~. ~, ~ .~ ALASSA OIL A1~TD GAS COI~SERQATIOI~T COMI~IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-102 ConocoPhillips Alaska, Inc. Permit No: 206-110 Surface Location: 2245' FSL, 2446' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 3735' FSL, 581' FEL, SEC. 11, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been .issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of August, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ~ ~~~~'~~® ALASKA OIL AND GAS CONSERVATION COMMISSIOt, ~~~ 2 6 2006 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas Cons. Commission 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone Q ~ 1 c.'Specify if well is p Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-102 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13688' • TVD: 3728' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2245' FSL, 2446' FEL, Sec. 35, T11 N, R10E, UM • 7. Property Designation: i ADL 25661 e& 25662 West Sak Oil Pool Top of Productive Horizon: 874' FSL, 590' FEL, Sec. 35, T11 N, R10E, UM • 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 8/17/2006 Total Depth: 3735' FSL, 581' FEL, Sec. 11, T10N, R10E, UM ` 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles ` 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558761 y- 5946057 ' Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance to Nearest ~~ Well within Pool: WSP-11 „~fl90' 16. Deviated wells: Kickoff depth: 300 ' ft. Maximum Hole Angle: g2° deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) Downhole: 1692 psig ' Surface: 1278 psig 18. Casing Program ecifications S Setting Depth Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 40' 40' 108' ' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2618' 40' 40' 2646' • 2243' 490 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 5979' 40' 40' 5988' ~ 3755' • 350 sx DeepCRETE 6.75" 4.5" 12.6# L-80 IBTM 8403' 5285' 3638' 13688' 3728' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee a BOP Sketch ^ Drilling Program ^ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~ Phone Date 7~~Sra6 ~ ~ 6 ~ E ~• 3d Pr ared b ha n All u -Drak Commission Use Only Permit to Drill / 1~ Number: ,Z.d~ - ~ ~V API Number: p 50- ~2,-(- 23 3 I `7 ~~ Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may n t be used to explore for, test, or produce coalbed,-methane, gash ates, or gas contained in shales: 3'oQC7. QS~ ~o~?~~~- C~5 ~ ~~~~ Samples req'd: Yes ^ No L"J ud log req'd: Yes ^ No [~ Other: H2S measures: Yes ^ No ~ e i nal svy req'd: Yes ~' No ^ V ~~ v~~ o P Ecc~~o h~ S c~cc~ ~ 1 A lO a- APPROVED BY THE COMMISSION DATE: ~/ ~~ ~ O ,COMMISSIONER Form 10-401 Revised 12/2005 Submi~ Duplicate /,+s~ 7 Z~•nL ?0'7 Conoco~illips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com July 24, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1J-102, 1]-102L1 and 1J-102L2 ,~.---~ Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a tri-lateral horizontal well in the West Sak ~~A2","B"and "D" sands. The main bore of the well will be designated 1]- 102, and the lateral bores of the well will be designated 1J-102L1 and 1J-102L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of iJ-102 is August 17, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, ~C 1~ ~ Randy Thomas` Greater Kuparuk Area Drilling Team Leader • Ap~n for Permit to Drill, Well 1J-102 Revision No.O Saved: 24-Jul-06 Permit It -West Sak Well #1J-102 App/ication for Permit to Dri// Document Mpxirtliz$ 1M~11 U'Qlue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fJ ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ..........................................................•--••--•-•-•-••--•-•-•--..................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) .........................................................................:.............:........... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 4 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals ........................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 1J-102 PERMIT IT Page 1 of 8 Printed: 24-Jul-06 GRIGI~~L ., Apron for Permit to Drill, Well 1J-102 Revision No.0 Saved: 24-Jul-06 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ...................................................................................................... ... 8 .... Attachment 1 Directional Plan (Including % Mile Radius Scan for Injector) .......................................... 8 Attachment 2 Drilling Hazards Summary .............................................................................................. 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ................................................................................................................ 8 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a welt with mu/tip/e wel/branches, each branch must sr`milarly be identified by a unique narrre and API number by adding a suffix to the name designated for the weti by fhe operator and to the number assigned to the we// by the commission, The well for which this Application is submitted will be designated as 1J-102. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fo% with the commission and identified in the application; (2) a plat identifying the property and the properfy's owners and showing (A)che coordinates of the proposed /acatian of the well at the sun`ace, at the top of each objective formation, and at total depth, referenced to governmental seetion lines (B) the coordinates of the proposed location of the we/I at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the Natonal Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2245' FSL & 2446' FEL -Sec 35 - T11N - R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 108' AMSL Northings: 5,946,057 Eastings: 558,761 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak "A2" Sand 874' FSL & 590' FEL -Sec 35 - T11N - R10E ASPZone 4 NAD 27 Coordinates Measured De th, RKB; 5,988 Northings: 5,944,700 Eastings: 560,629 Total l/ertica/De th, RKB: 3,755 Total t/ertica/ De th, SS.' 3,634 Location at Total De th 3735' FSL & 581' FEL -Sec 11 - T10N - R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.' 13, 688 Northings: 5,937,003 Eastings: 560,706 Total t/ertica/De th, RKB: 3,728 Total l/ertical De th,' SS.' 3,607 and 1J-102 PERMIT IT Page 2 of 8 ` , ~ ~ Printed: 24-Jul-O6 Ap~on for Permit to Drill, Well 1J-102 Revision No.O Saved: 24-Jul-06 (®) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) If a we/1 is to be intentiana//y deviated, the application for a Permit to Drif/ (Farm 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including afl adjacent wellbores within 200 feet of any pardon of the proposed we!/; Please see Attachment 1: Directional Plan and (2) for all we/!s within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or dr"scoverab/e in pub/ic records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application far a Permit to Dri// must be accompanied by each of the following items, except For an item already on file with the commission and identified in the application; (3) a diagram and description of the 6/owout prevention equipment (BCJPFJ as required by 20 AAC25.035, 20 AAC25 036, or 20 AAC25.037, as applicable; ~VZ tl~' .2?~ ~ ~ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J~.3~. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to /Jrifl must 6e accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,278 psi, calculated: MPSP =(3,761 ft TVD)(0.45 - 0.11 psi/ft) =1,278 psi ' (B) data on potentia/gas zones The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-102 Drilling Hazards Summary. 5. Procedure for Conducting- Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ieation for a Permit to drill must be accompanied by each of the fallowing items, except far an item already on file with the commission and identified in the application.• (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); 1J-102 PERMIT IT Page 3 of 8 Printed: 24-Jul-06 QRlGII~AL Ap~on for Permit to Drill, Well 1J-102 Revision No.O Saved: 24-Jul-06 iJ-102 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application far a Fermit to flri!! must be accompanied 6y each of the fal/awr`ng items, except for an item a/ready on file with the commission and identified in the applicatian: <~1 a cantplete prapased casing and cementing program as required by 20 AAC 25.03(J, and a descriptian of any slatted finer, pre- perforated liner, or screen to be instal/ed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top elm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 40 / 40 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,618 40 / 40 2,646 /2,243 490 sx ASLite Lead, drift 180 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 5,979 40 / 40 5,988 / 3,755 3,199' MD / 2,630' TVD. Cemented w/ 350 sx Dee CRETE 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 8,403 5,285 / 3,638 13,688 / 3,728 Slotted- no cement Slotted Lateral (1]-102) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,307 5,185/ 3,621 12,492 / 3,582 Slotted- no cement Slotted Lateral (1J-102 Ll) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,322 4,865/ 3,551 12,187 / 3,509 Slotted- no cement Slotted Lateral (iJ-102 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicatr"an for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application.' (7) a diagram and description of the diverter system as required by 20 AAC 25, t135, unless this requirement is waived by the. commission under 2l1 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-102. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except far an item already on rile with the cammission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.1133,• Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 9.5 9.6 1J-102 PERMIT IT Page 4 of 8 r Printed: 24-Jul-06 • Ap~on for Permit to Drill, Well 1J-102 Revision No.0 Saved: 24-Jul-06 Funnel Viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 cP Plastic Viscosity 20 45 15 20 Ib/100 s PH 8.5 9.0 8.5 9.0 API Filtrate cc / 30 min NC 8.0 5.0 7.0 *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4"Cs Shoe to 7-5/8"Cs Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity 45 - 60 seconds) Plastic Viscosity 12 - 18 (Ib/100 sf) Yield Point 26 - 35 (cP) API Filtrate 4 - 6 cc / 30 min)) Chlorides (mg/I) <500 pH 9.0 - 9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) AIB/D sand laterals Value Density (ppg) 8.6 Plastic Viscosity 15 - 25 lb/100 s fl Yield Point 18 28 cP) HTHP Fluid loss (mI/30 min <4 0 @ 200psi & . 150° Oil /Water Ratio 70 / 30 Electrical >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Drill must be accompanied by each of the fa/lowr`ng items, except for an item a/ready on file with the commission and identified in the application: (9) for an exp/oratory or stratigraphic test well, a tabuNation setting out the depths of predicted abnormally geo pressured strata as required by 2f1 AAG ZS.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (IQ) for an exp/oratory or stratigraphic test we!/, a seismic refraction or reflection analysis as required by 20 AAC 25.061(x); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application far a Permit fo Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) fora well drilled from an offshore platform, mabi/e bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by 20AAC25.061(b); ORIGINAL 1J-102 PERMIT IT Page 5 of 8 Printed: 24-Jul-06 v Not applicable: Application is not for an offshore well. Ap~on for Permit to Drill, Well 1J-102 Revision No.0 Saved: 24-Jul-06 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Qrill must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application; (i2) evidence shaving that the requirements of20 AAC25.(12S {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to L)rill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the app/icatian: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 120' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Install 21-1/4"Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,646' MD / 2,243' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 his before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 5,988 MD / 3,755' TVD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud to 3,199' MD / 2,630' TVD. (500' MD above the Ugnu C sand). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD. logging tools.. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 13,688' MD / 3,728' TVD as per directional plan. 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. Run USIT log for cement bond. ~~Tg P~~~-~- ~p~~~~~d~ ~---, 17. PU and run 4-1/2" slotted liner. /~ 18. Land liner, set liner hanger @ +/- 5,285' MD / 3,538' TVD. POOH. 1J-102 PERMIT IT Page 6 of 8 Printed: 24-Jul-06 ORIGINAL Ap~on for Permit to Drill, Well 1 J-102 Revision No.O Saved: 24-J u1-06 Note: Remaining operations are covered under the 1J-102L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 5,185' MD / 3,621' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pickup 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 12,492' MD / 3,582' TVD, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 24~ RIH with whipstock retrieval tool. Retrieve whipstock a,nd POOH. 25. PU and run 4-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 1J-102L2 Application for Permit to Drill, and are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 4,865' MD / 3,551' TVD, the top of the D sand. 30. Mill 6-3/4" window. POOH. 31. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 12,187' MD / 3,509' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 3S. PU and run 4-1/2"slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. POOH. 38. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 39. POOH, laying down drill pipe as required. 40. PU completion as required and RIH to depth. Land tubing. Set BPV 41. Nipple down BOPE, nipple up tree and test. Pull BPV. 42. Freeze protect well with diesel. 43. Set BPV and move rig off. 44. Rig up wire line unit. Pull BPV. 45. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 46. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 1J-102 PERMIT IT Page 7 of 8 Printed: 24-Jul-O6 C7 Ap~on for Permit to Drill, Well 1J-102 Revision No.O Saved: 24-Jul-06 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to flriil must be accompanied 6y each of the following items, except for an item a/ready on fr/e with the cammission and identified in the application: (14J a general description of how the aperator plans to dispose of drillr`ng mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.08® for an annular dispose/ aperation in the wel%; Waste fluids generated during the drilling process will be disposed. of either by pumping authorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan (Including % Mile Radius Scan for Injector) Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic 1J-102 PERMIT IT Page 8 of 8 Q ~ ~ ~ ~ ~ ~ ~ Printed: 24-Jul-06 ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-102 -Slot 1J-102 1J-102 Plan: 1J-102 (wp07) Proposal Report 20 May, 2006 C7 AL.~l. "r~t~l' Sperry Drilling Services OR161NAL . -400 ' Project: Kuparuk River Uni ° CASING DETAILS /10 KOP ~ 300ft MD, 30oft ND-Build @ 2.5 Site: Kuparuk 1J Pad ' Continue Buildrrum ~ 3.5°/100' : 70zft MD, 7ooft N~ Well: Plan 1J-102 No MD ND TVDss Name Size Wellbore: 1J-102 1 120.00 120.00 -1 16" 16 ~ ,~ sail @41.3° Inc : 1601ft MD, 1500ft NI~ Plan: 1J-102 (wp07) 2 2645.82 2243.00 2122 10 3/4" " 10-3/4 ' ~ 3 5987.90 3754.90 3633.9 7 5/8 7-5/8 ' 413688.19 3728.00 3607 41/2" 4-1/2 ~ Continue BuildlTum ~ 4.5°/100' : 1701ft MD, 1575ft r ~ i i FORMATION TOP DETAILS ~ NoNDPath NDSS MOPath Formation Continue Tum ~ 4.5°I100' : 1846ft MD, 1680ft 1 1533.00 1412 1644.52 Base Perm ~ ~ 2 1671.00 7550 1633.69 T3 i ~ ~ 3 1962.00 1841 2246.77 K15 ' Sail 45.4° Inc : 1796ft MD -1645ft N ~ ~ 4 2243.00 2122 2645.82 T3 + 550 ~ ~ , ' 5 2987.00 2866 3690.24 Ugnu C ' ~ 6 3230.00 3109 4065.23 Ugnu B , ' 7 3311.00 3190 4209.74 Ugnu A Sail ~ 45.4° Inc : 2051ft MD, 1824ft N 8 3417.00 3296 4430.93 K13 '• / 9 3551.00 3430 4865.07 Wsak D 16 ~ 10 3592.00 3471 5047.31 Wsak C ' 11 3620.00 3499 5179.44 Wsak 8 0, , , 12 3657.00 3536 5392.44 Wsak A4 - 13 1688.00 3567 5570.97 Wsak A3 " -' ~ Continue Tum X4.5°/100' : 2101ft MD, 1859ft N 14 3750.90 3629.9 5948.18 Wsak A2 1 - ' ' ~ Sail ~ 45.2° Inc : 2338ft MD, 2026ft N X09' '~~ _-'"~~_ _--~~~_'-_- ' _ - _ - - Continue Tum ~ 5°/100' : 2388ft MD, 2062ft N __~`__-------- - __ __~_--------- _ =----- - ---- ~" -- - - - --- Base Perm -- - __ _ - _ _ , _~ --- -- _°----=----f--=~=-------------"__---------------Sail~45.4°Inc:2541ftMD,2170ftN ----- T3------------ - - - - - _ _ 10 3/4" Cs 2646ft MD. 2243ft N -- --- ----------- --- ------- ------------ ---------------- - a = - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - T3 + 550 - - - - -- -ContinueBuild/Tum~ 5°/100':3039ft'MD,2519ftN~ ~° ------------------------- Minimum Inclination during tum :43.26°, 3350ft MD, 2743ft ------------------------------ -- Sail ~ 77° Inc : 4785ft MD, 3533ft Begin Build ~ 4°/100' : 6008ft MD, 3757ft N i - - - - - - - - - - - - - - - - - - - - - - ' - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Ugnu C - - - - - - - - { - - -~ .' '~ i 0 . ~ Sail ~ 80° Inc : 5185ft MD, 3621ft , - ' ~ 1J-102 L2 (wp07 _ _ _ _ _ _ _ _ _ _ _ Ugnu B - - - - - - - - - - - - - - - - - - - - - - - - - ro - - - ~- - - - - - - - - - - - - - - - - - - " - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -_ ~_ _, - -- --^6--- -----------------_" ---------------------- UgnuA 1J-102 L1(wp07 - K13 - - - - - o - " Wsak D = _ __ _ - -_ - - - - - - - - - - - - - -_ - -_ -_ -_ -_ -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Wsak C ~ ~ ~ ` `` ` i ~ ~ ~ ~ \ `WSakB ~i ~~ `~ ~~ ~ \ i ~ `\ Wsak A4 i ~ 1J-102 T2 (wp07 1J-102 T3 (wp07 ~ ' ~ Wsak A3 ~ ~ i ~ Wsak A2 1J-102 T1 (D toP) (wP07 ~ ~~ 75!8" Csg ~ 5988ft MD, 3755ft N Begin Build/Tum ~ 4°/100' : 5107ft MD, 3605ft HALLIBURTON Begin Build ~ 4°I100' : 5860ft MD, 3738ft N Continue GeoSteer in Upper Lobe of A2 Sand, 6371ft MD, 3755ft Spa°ry DriNilny S~Irvic~s -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 Vertical Sectron at 180.00" (1000 ftlinj I ° ,"~" i / i ~ i 1J-102 T4 (wp07 ~ i i i .~/ ~ i 1J-102 T5(Toe)(wp07 r BHL ~ 13688ft MD, 3728ft TVD - 4 1/2 ConocoPhillips Alaska 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 Sall ~ 45.4° Inc : 2051ft~4ft Nd ~ Continue Tum ~ 4.5° 800 CoMlnue Tum ~ID 4.5°/100' : 1846ft MD, 16808 400 Sail ~ 45.4° Inc : 1796ft MD - 1645ft N - - - - - - - Continue Build/Tum LID 4.5°/100' : 1701ft MD, 1575ft N -' 0 ,,,~ y 00 -400 Sail ~ 41.3° Inc : 1601ft MD, 1500ft N ~ ~ 1 i~ _gOp Continue BuildlTum ~ 3.5°1100' : 702ft MD, 700ft -1200 I KOP ~ M300ft D,. 300ft ND - Build ~ 2.5°/100' No O~ w ~ o ~ ~° 10 3/4" Csg ~ 2646ft MD, 2243ft N 15~ Sail ~ 77° Inc : 4765ft MD, 3533ft N 175° , -' _' _ _ _ _ _ _ _ Begin Tum ~ 0.83°/100' : 4865ft MD, 3551ft N _ _ _ _ _ _ _ _ _ _ _ _ _ Begin BuildlTum ~ 4°N 00' : b107ft MD, 3605ft N Sall ~ 80° Inc : 5185ft MD, 3621ft N 183° Begin Build LID 4°/100' : 5860ft MD, 3738ft N _,_----------"- Sa11~85°Inc:5988ftMD,3755ftN I ~'~ ~'- l ``~~~ i~~, ~~~ i Begin Build ~ 4°/100' : 6008ft MD, 3757ft N I I `~~ I ~~, I Continue GeoSteer in Upper Lobe of A2 Sand, 6371ft MD, 3755ft t 1J-102 T1 (D top) (wp07 -1600 --~-~ ~~~~ 7 5/8" Csg @ 5988ft MD, 3755ft N c 0 0 0 L 0 Z t 3 0 1J-102 DD Poly @ 95%(wp07) DD Polygon Describes a corridor 100' wide with a 50'+/-allowance ENV from the orooosed wellbore. 1 Project: Kuparuk River Unit t Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1 J-102 I Plan: 1J-102 (wp07) ~ I 1 i i i 1J-102 Geo Poly (wp07) i DD Polygon portrays the maximum positional uncertain @ 95% confidence, if actual wellpath is at outer i edge of Red DD polygon. - - - ---+ i i I I I T M.zinuths to True "forth Magnetic North: 23.88° Magnetic Field Strength:57604.OnT Dip Angle: 80.80° Date: 7/1 /2006 Model: BGGM2006 CASING DETAILS No MD TVD TVDss Name Size 1 120.00 120.00 -1 16" 16 2 2645.82 2243.00 2122 10 3/4" 10-3/4 3 5987.90 3754.90 3633.9 7 5/8" 7-5/8 4 13688.19 3728.00 3607 41/2" 4-1/2 2101ft MD,1859ft ,due Build/Tum ~ 5°/100' : 3039ft' MD, 2519ft NI - - - - - - Minimum Inclination during tum :43.26°, 3350ft MD, 2743ft N I 1 I i 1 I 1 ~ - - - - - - - - 1J-102 T2 (wp07 1 t I I I i----- I 1J-102 T3 (wp07 I HALLIf3tJRTON Sperry Orflliny Servkes I I `. ConocoPhillips I Alaska I I I _ 1J-102 T4 (wp07 I ----- l_---' I t I I i I 1J-102 T5 (Toe)(wp07 i _____ _ ~- ~ - ~._ BHL @ 136888 MD, 3728ft ND - 4 112' ' -2400 -2000 -1600 -1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 r'1 f'1 t iWle6t~r)/~ayr;(+a (1000 ft/in) Halliburton Energy Services ~ lE-tA~i.>IguRTON ~(~-~"1QC©~'11~'~~S Planning Report -Geographic -~ ---~°°~~~------°r~~ Alaska Database: _EDM_2003.11_b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1 J Pad Well: Plan 1J-102 Wellbore: 1 J-102 Design: 1J-102 (wp07) Sperry Dr'iMlieeg Serviaea Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor - -- - __ ~ Well Plan 1J-102 -Slot 1J-102 Well Position +N/-S 0.00 ft Northing: 5,946,056.80 ft +E/-W 0.00 ft Easting: 558,761.70 ft Position Uncertainty 0.00 ft Wellhead Elevation: ft Latitude: 70° 15' 47.609" N Longitude: 149° 31' 29.797" W Ground Level: 81.OOft Wellbore 1J-102 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2006 7/1/2006 23.88 80.80 57,604 Design - 1J-102 (wp07) _ -- _ __ - Audit Notes: Version: 10 Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) +N/S +E/-W Direction (ft) (ft) (ft) (°) 40.00 0.00 0.00 180.00 5/20/2006 1:17:35PM Page 2 of 11 COMPASS 2003.11 Build 50 '` ~ H E i • llib t S " ur on nergy erv ces a HA-I.C.EE#URTt~N ~C)1 1QeQ ~11~~f~3S Planning Report -Geographic -~---~~--~-----~-----~--~-~ Alaska S~~ nrilltng Sa~rvices Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature , Wellbore: 1 J-102 Design: 1J-102 (wp07) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-5 +E/_W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°l100ft) (°1100ft) (°/100ft) (°) 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 702.06 10.05 30.00 700.00 30.46 17.59 2.50 2.50 0.00 30.00 1,600.58 41.31 39.85 1,500.00 333.72 252.77 3.50 3.48 1.10 12.50 1,700.58 41.31 39.85 1,575.11 384.41 295.07 0.00 0.00 0.00 0.00 1,796.10 45.35 42.00 1,644.58 433.88 338.03 4.50 4.23 2.25 20.87 1,846.10 45.35 42.00 1,679.72 460.32 361.83 0.00 0.00 0.00 0.00 2,051.40 45.35 55.00 1,824.31 556.68 470.75 4.50 0.00 6.33 94.58 2,101.40 45.35 55.00 1,859.45 577.09 499.89 0.00 0.00 0.00 0.00 2,337.97 45.23 70.00 2,026.36 654.30 648.16 4.50 -0.05 6.34 95.93 2,387.97 45.23 70.00 2,061.57 666.44 681.51 0.00 0.00 0.00 0.00 2,541.35 45.38 80.79 2,169.61 693.83 786.71 5.00 0.10 7.04 92.70 3,039.02 45.38 80.79 2,519.20 750.50 1,136.37 0.00 0.00 0.00 0.00 4,785.07 77.00 180.00 3,533.00 -190.20 1,904.44 5.00 1.81 5.68 105.66 4,865.07 77.00 180.00 3,551.00 -268.15 1,904.44 0.00 0.00 0.00 0.00 5,106.57 77.00 182.00 3,605.33 -503.41 1,900.33 0.81 0.00 0.83 90.22 5,185.47 80.00 183.00 3,621.06 -580.64 1,896.96 4.00 3.80 1.27 18.19 5,860.47 80.00 183.00 3,738.27 -1,244.48 1,862.17 0.00 0.00 0.00 0.00 5,987.90 85.00 182.00 3,754.90 -1,370.66 1,856.66 4.00 3.92 -0.78 348.72 6,007.90 85.00 182.00 3,756.64 -1,390.57 1,855.97 0.00 0.00 0.00 0.00 6,184.46 92.03 182.66 3,761.21 -1,566.81 1,848.80 4.00 3.98 0.37 5.37 6,370.70 92.03 182.66 3,754.61 -1,752.73 1,840.16 0.00 0.00 0.00 0.00 6,440.81 90.84 180.12 3,752.85 -1,822.79 1,838.46 4.00 -1.70 -3.62 -115.11 8,340.81 90.84 180.12 3,725.00 -3,722.59 1,834.48 0.00 0.00 0.00 0.00 8,389.13 89.05 179.40 3,725.05 -3,770.90 1,834.69 4.00 -3.71 -1.50 -158.04 9,128.26 89.05 179.40 3,737.34 -4,509.89 1,842.46 0.00 0.00 0.00 0.00 9,167.35 90.61 179.45 3,737.45 -4,548.97 1,842.85 4.00 4.00 0.14 1.94 9,867.35 90.61 179.45 3,730.00 -5,248.90 1,849.57 0.00 0.00 0.00 0.00 9,902.23 89.22 179.38 3,730.05 -5,283.78 1,849.93 4.00 -3.99 -0.21 -177.01 10,480.10 89.22 179.38 3,737.96 -5,861.56 1,856.21 0.00 0.00 0.00 0.00 10,501.98 90.06 179.61 3,738.09 -5,883.44 1,856.40 4.00 3.86 1.06 15.43 12,501.98 90.06 179.61 3,736.00 -7,883.39 1,870.02 0.00 0.00 0.00 0.00 12,514.97 90.39 179.82 3,735.95 -7,896.38 1,870.08 3.00 2.53 1.62 32.65 " 13,688.19 90.39 179.82 3,728.00 -9,069.57 1,873.76 0.00 0.00 0.00 0.00 5/20/2006 7:17:35PM Page 3 of 11 COMPASS 2003.11 Build 50 ORIGINAL • Halliburton Energy Services ~ HAt~LtBJ~'tTt~N C©nocoPhi~lip~s Planning Report -Geographic ---~---- -~ Sperry Drittir,g Serviceu Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska lnc. TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-102 Design: 1J-102 (wp07) Planned Survey 1J-102 (wp07) MD Inclination Azimuth TVD SSTVD +NI-S (ft) (°) (°) (ft) (ft) (ft) 40.00 0.00 0.00 40.00 -81.00 0.00 • SHL - 2245ft FSL & 2446ft FEL - Sec35 - T11 N - R10E 100.00 0.00 0.00 100.00 -21.00 0.00 120.00 0.00 0.00 120.00 -1.00 0.00 20" 200.00 0.00 0.00 200.00 79.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 KOP @ 300ft MD, 300ft TVD -Build @ 2.5°/100' 400.00 2.50 30.00 399.97 278.97 1.89 500.00 5.00 30.00 499.75 378.75 7.55 600.00 7.50 30.00 599.14 478.14 16.98 700.00 10.00 30.00 697.97 576.97 30.15 702.06 10.05 30.00 700.00 579.00 30.46 Continue Build/Turn @ 3.5°/100' : 702ft MD, 700ft TVD 800.00 13.42 33.20 795.88 674.88 47.38 900.00 16.88 35.16 892.39 771.39 68.97 1,000.00 20.36 36.47 987.14 866.14 94.83 1,100.00 23.84 37.41 1,079.78 958.78 124.88 1,200.00 27.32 38.12 1,169.97 1,048.97 159.00 1,300.00 30.81 38.68 1,257.36 1,136.36 197.07 1,400.00 34.31 39.14 1,341.63 1,220.63 238.93 1,500.00 37.80 39.52 1,422.46 1,301.46 284.44 1,600.00 41.29 39.85 1,499.56 1,378.56 333.43 1,600.58 41.31 39.85 1,500.00 1,379.00 333.72 Sail @ 41.3° Inc : 1601ft MD, 1500ft TVD 1,644.52 41.31 39.85 1,533.00 1,412.00 355.99 Base Perm 1,700.00 41.31 39.85 1,574.67 1,453.67 384.11 1,700.58 41.31 39.85 1,575.11 1,454.11 384.41 Continue Build/Turn @ 4.5°/100' : 1701ft MD, 1575ft TVD 1,796.10 45.35 42.00 1,644.58 1,523.58 433.88 Sail @ 45.4° Inc : 1796ft MD - 1645ft TVD 1,800.00 45.35 42.00 1,647.32 1,526.32 435.95 1,833.69 45.35 42.00 1,671.00 1,550.00 453.76 T3 1,846.10 45.35 42.00 1,679.72 1,558.72 460.32 Continue Turn ~ 4.5°/100' : 1846ft MD, 1680ft TVD 1,900.00 45.21 45.41 1,717.65 1,596.65 488.00 2,000.00 45.21 51.75 1,788.14 1,667.14 534.90 2,051.40 45.35 55.00 1,824.31 1,703.31 556.68 Sail @ 45.4° Inc : 2051ft MD, 1824ft TVD 2,100.00 45.35 55.00 1,858.47 1,737.47 576.52 2,101.40 45.35 55.00 1,859.45 1,738.45 577.09 Continue Turn @ 4.5°/100' : 2101ft MD, 1859ft TVD Map Map +EI_VU Northing Easting (ft) (ft) (ft) 0.00 5,946,056.80 558,761.70 0.00 5,946,056.80 558,761.70 0.00 0.00 0.00 5,946,056.80 558,761.70 0.00 0.00 -- , DLSEV Vert Section ; (°/100ft) (ft) 0.00 0.00 0.00 5,946,056.80 558,761.70 0.00 0.00 0.00 5,946,056.80 558,761.70 0.00 0.00 1.09 5,946,058.70 4.36 5,946,064.39 9.80 5,946,073.85 17.41 5,946,087.09 17.59 5,946,087.40 28.09 5,946,104.39 42.81 5,946,126.09 61.51 5,946,152.10 84.13 5,946,182.32 110.58 5,946,216.65 140.77 5,946,254.94 174.57 5,946,297.06 211.87 5,946,342.86 252.53 5,946,392.16 252.77 5,946,392.45 271.36 5,946,414.86 294.83 5,946,443.16 295.07 5,946,443.46 338.03 5,946,493.27 339.89 5,946,495.34 355.93 5,946,513.28 361.83 5,946,519.88 388.28 5,946,547.77 441.45 5,946,595.08 470.75 5,946,617.09 499.07 5,946,637.14 499.89 5,946,637.71 558,762.78 558,766.00 558,771.37 558,778.87 558,779.05 558,789.41 558,803.96 558,822.46 558,844.84 558,871.03 558,900.91 558,934.38 558,971.32 559,011.59 559,011.84 559,030.24 559,053.49 559,053.74 559,096.30 559,098.14 559,114.04 559,119.89 559,146.13 559,198.92 559,228.05 559,256.21 559,257.02 2.50 -1.89 2.50 -7.55 2.50 -16.98 2.50 -30.15 2.50 -30.46 3.50 -47.38 3.50 -68.97 3.50 -94.83 3.50 -124.88 3.50 -159.00 3.50 -197.07 3.50 -238.93 3.50 -284.44 3.50 -333.43 3.50 -333.72 0.00 -355.99 0.00 -384.11 0.00 -384.41 4.50 -433.88 0.00 -435.95 0.00 -453.76 0.00 -460.32 4.50 -488.00 4.50 -534.90 4.50 -556.68 0.00 -576.52 0.00 -577.09 5/20/2006 1:17:35PM Page 4 of 11 COMPASS 2003.11 Build 50 ~~~.~ ti•-' ~ Halliburton Energy Services • HALILt~caRroN ~~~«~~~~~~~ Planning Report -Geographic -----~-_~_ - q~~ Sperry grilling Services Database: _EDM_2003.11_ b48 Local Co-ordinate Reference: Well Plan 1J -102 -Slot 1J-1 02 Company: ConocoPhillips Alaska Inc. ND Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (8 1+40)) Project: Kuparuk River U nit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (8 1+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Cu rvature Wellbore: 1 J-102 Design: 1J-102 (wp07) Planned Survey 1J-102 (wp07) _ ___ __ __ _ Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) lft) {ft) (°/100ft) (ft) 2,200.00 45.06 61.24 1,928.96 1,807.96 614.01 559.24 5,946,675.10 559,316.08 4.50 -614.01 2,246.77 45.04 64.21 1,962.00 1,841.00 629.18 588.66 5,946,690.49 559,345.37 4.50 -629.18 K15 2,300.00 45.12 67.60 1,999.59 1,878.59 644.56 623.06 5,946,706.14 559,379.65 4.50 -644.56 2,337.97 45.23 70.00 2,026.36 1,905.36 654.30 648.16 5,946,716.07 559,404.67 4.50 -654.30 Sail @ 45.2° Inc : 2338ft MD, 2026ft ND 2,387.97 45.23 70.00 2,061.57 1,940.57 666.44 681.51 5,946,728.47 559,437.93 0.00 -666.44 Continue Turn @ 5°/100' : 2388ft MD, 2062ft ND 2,400.00 45.20 70.85 2,070.05 1,949.05 669.30 689.56 5,946,731.39 559,445.95 5.00 -669.30 2,500.00 45.24 77.89 2,140.53 2,019.53 688.40 757.83 5,946,751.02 559,514.07 5.00 -688.40 2,541.35 45.38 80.79 2,169.61 2,048.61 693.83 786.71 5,946,756.68 559,542.90 5.00 -693.83 Sail @ 45.4° Inc : 2541ft MD, 2170ft ND 2,600.00 45.38 80.79 2,210.81 2,089.81 700.51 827.92 5,946,763.68 559,584.05 0.00 -700.51 2,645.82 45.38 80.79 2,243.00 2,122.00 705.73 860.12 5,946,769.15 559,616.20 0.00 -705.73 10 3/4" Csg @ 21i46ft MD, 2243ft ND : 2951ft FSL 8~ 1585ft FEL - Sec35 - T11 N - R7 OE - T3 + 550 -10 314" 2,700.00 45.38 80.79 2,281.06 2,160.06 711.90 898.18 5,946,775.61 559,654.21 0.00 -711.90 2,800.00 45.38 80.79 2,351.30 2,230.30 723.28 968.44 5,946,787.55 559,724.37 0.00 -723.28 2,900.00 45.38 80.79 2,421.54 2,300.54 734.67 1,038.70 5,946,799.48 559,794.53 0.00 -734.67 3,000.00 45.38 80.79 2,491.78 2,370.78 746.06 1,108.96 5,946,811.42 559,864,70 0.00 -746.06 3,039.02 45.38 80.79 2,519.20 2,398.20 750.50 1,136.37 5,946,816.07 559,892.07 0.00 -750.50 Continue Build/Turn @ 5°/100' : 3 039ft' MD, 2519ft ND 3,100.00 44.63 84.97 2,562.32 2,441.32 755.85 1,179.14 5,946,821.75 559,934.80 5.00 -755.85 3,200.00 43.75 92.04 2,634.07 2,513.07 757.70 1,248.73 5,946,824.15 560,004.36 5.00 -757.70 3,300.00 43.31 99.27 2,706.62 2,585.62 750.94 1,317.17 5,946,817.92 560,072.85 5.00 -750:94 3,350.00 43.26 102.92 2,743.02 2,622.02 744.34 1,350.80 5,946,811.59 560,106.52 5.00 -744.34 Minimum I nclination during turn : 43.26°, 3350ft MD, 2743ft ND 3,400.00 43.33 106.56 2,779.42 2,658.42 735.62 1,383.95 5,946,803.13 560,139.74 5.00 -735.62 3,500.00 43.82 113.78 2,851.91 2,730.91 711.86 1,448.56 5,946,779.88 560,204.52 5.00 -711.86 3,600.00 44.74 120.82 2,923.55 2,802.55 679.85 1,510.50 5,946,748.35 560,266.70 5.00 -679.85 3,690.24 45.94 126.94 2,987.00 2,866.00 644.07 1,563.71 5,946,712.99 560,320.19 5.00 -644.07 Ugnu C 3,700.00 46.09 127.59 2,993.78 2,872.78 639.81 1,569.30 5,946,708.78 560,325.81 4.99 -639.81 3,800.00 47.81 134.01 3,062.08 2,941.08 592.07 1,624.53 5,946,661.47 560,381.40 5.00 -592.07 3,900.00 49.88 140.06 3,127.92 3,006.92 536.97 1,675.74 5,946,606.78 560,433.04 5.00 -536.97 4,000.00 52.23 145.74 3,190.81 3,069.81 474.95 1,722.57 5,946,545.14 560,480.34 5.00 -474.95 4,065.23 53.91 149.24 3,230.00 3,109.00 430.99 1,750.57 5,946,501.40 560,508.69 5.00 -430.99 Ugnu B 4,100.00 54.85 151.04 3,250.25 3,129.25 406.47 1,764.64 5,946,476.99 560,522.95 5.00 -406.47 4,200.00 57.67 156.00 3,305.81 3,184.81 332.06 1,801.65 5,946,402.88 560,560.53 5.00 -332.06 4,209.74 57.96 156.46 3,311.00 3,190.00 324.52 1,804.97 5,946,395.36 560,563.91 5.01 -324.52 Ugnu A 4,300.00 60.68 160.65 3,357.06 3,236.06 252.28 1,833.30 5,946,323.35 560,592.80 5.00 -252.28 4,400.00 63.85 165.02 3,403.61 3,282.61 167.73 1,859.36 5,946,239.02 560,619.51 5.00 -167.73 5/20f2006 1:17:35PM Page 5 of 11 COMPASS 2003.11 Build 50 ~~~1~~ • Halliburton Energy Services ~ HAI.#..fBURT(DN ~411000~11~~Ep5 Planning Report -Geographic --------~~~--~~n~----~-° ---- Alaska +p~nY Drilling Siervices Database: EDM 2003.11 b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1 J-102 Design: 1J-102 (wp07) Planned Survey 1J-102 (wp07) Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1 J-102 TVD Reference: Doyon 15 Plah @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature MD Inclination Azimuth TVD SSTVD +N/-S +E/-W (ft) (°) (°) (ftl (ft) (ft) (ft) 4,430.93 64.85 166.33 3,417.00 3,296.00 140.72 1,866.25 K13 4,500.00 67.13 169.17 3,445.10 3,324.10 79.07 1,879.63 4,600.00 70.52 173.11 3,481.22 3,360.22 -13.04 1,893.95 4,700.00 74.00 176.89 3,511.70 3,390.70 -107.89 1,902.22 4,785.07 77.00 180.00 3,533.00 3,412.00 -190.20 1,904.44 Sail @ 77° Inc : 4785ft MD, 3533ft TVD 4,800.00 77.00 180.00 3,536.36 3,415.36 -204.74 1,904.44 4,865.07 77.00 180.00 3,551.00 3,430.00 -268.15 1,904.44 Begin Turn @ 0.83°/100' : 4865ft MD, 3551ft TVD - Wsak D -1J-102 T1 (D top) (wp07) 4,900.00 77.00 180.29 3,558.86 3,437.86 -302.18 1,904.35 5,000.00 77.00 181.12 3,581.36 3,460.36 -399.61 1,903.16 5,047.31 77.00 181.51 3,592.00 3,471.00 -445.70 1,902.10 Wsak C 5,100.00 77.00 181.95 3,603.85 3,482.85 -497.01 1,900.55 5,106.57 77.00 182.00 3,605.33 3,484.33 -503.41 1,900.33 Begin Buil d/Turn @ 4°/7 00' : 5107ft MD, 3605ft TVD 5,179.44 79.77 182.92 3,620.00 3,499.00 -574.71 1,897.26 Wsak B 5,185.47 80.00 183.00 3,621.06 3,500.06 -580.64 1,896.96 Sail ~ 80° Inc : 5185ft MD, 3621ft TVD 5,200.00 80.00 183.00 3,623.58 3,502.58 -594.93 1,896.21 5,300.00 80.00 183.00 3,640.95 3,519.95 -693.28 1,891.05 5,392.44 80.00 183.00 3,657.00 3,536.00 -784.19 1,886.29 Wsak A4 5,400.00 80.00 183.00 3,658.31 3,537.31 -791.62 1,885.90 5,500.00 80.00 183.00 3,675.68 3,554.68 -889.97 1,880.75 5,570.97 80.00 183.00 3,688.00 3,567.00 -959.76 1,877.09 Wsak A3 5,600.00 80.00 183.00 3,693.04 3,572.04 -988.31 1,875.59 5,700.00 80.00 183.00 3,710.41 3,589.41 -1,086.66 1,870.44 5,784.04 80.00 183.00 3,725.00 3,604.00 -1,169.31 1,866.11 Map Map Northing Easting (ft) (ft) 5,946,212.06 560,626.62 1 I DLSEV Vert Section (°7100ft) (ft) 5.00 -140.72 5,946,150.53 560,640.47 5.00 -79.07 5,946,058.54 560,655.51 5.00 13.04 5,945,963.77 560,664.52 5.00 107.89 5,945,881.49 560,667.38 5.00 190.20 5,945,866.94 560,667.50 0.00 204.74 5,945,803.55 560,667.99 0.00 268.15 5,945,769.52 560,668.17 0.81 302.18 5,945,672.09 560,667.74 0.81 399.61 5,945,626.00 560,667.04 0.81 445.70 5,945,574.68 560,665.89 0.81 497.01 5,945,568.28 560,665.72 0.81 503.41 5,945,496.97 560,663.21 4.00 574.71 5,945,491.03 560,662.95 4.00 580.64 5,945,476.74 560,662.31 0.00 594.93 5,945,378.37 560,657.93 0.00 693.28 5,945,287.43 560,653.87 0.00 784.19 5,945,279.99 560,653.54 0.00 791.62 5,945,181.62 560,649.15 0.00 889.97 5,945,111.81 560,646.04 0.00 959.76 5,945,083.25 560,644.77 0.00 988.31 5,944,984.87 560,640.38 0.00 1,086.66 5,944,902.20 560,636.70 0.00 1,169.31 5,800.00 80.00 183.00 3,727.77 3,606.77 -1,185.01 1,865.28 5,944,886.50 560,636.00 0.00 5,860.47 80.00 183.00 3,738.27 3,617.27 -1,244.48 1,862.17 5,944,827.01 560,633.34 0.00 Begin Build @ 4°l100' : 5860ft MD, 3738ft TVD 5,900.00 81.55 182.69 3,744.61 3,623.61 -1,283.44 1,860.23 5,944,788.03 560,631.71 4.00 5,948.18 83.44 182.31 3,750.90 3,629.90 -1,331.16 1,858.15 5,944,740.31 560,630.00 4.00 Wsak A2 5,987.90 85.00 182.00 3,754.90 3,633.90 -1,370.66 1,856.66 5,944,700.81 560,628.83 4.00 Sail @ 85° Inc : 5988ft MD, 3755ft TVD - 7 5/8" Csg @ 5988ft MD, 3755ft TVD : 874ft FSL 8 590ft FEL - Sec35 - T11 N - R 1 OE - 7 5/8" 6,000.00 85.00 182.00 3,755.95 3,634.95 -1,382.70 1,856.24 5,944,688.76 560,628.50 0.00 1,185.01 1,244.48 1,283.44 1,331.16 1,370.66 1,382.70 5/20/2006 1:17:35PM Page 6 of 11 COMPASS 2003.11 Build 50 r~° , ~ Halliburton Energy Services • HA6..LIBURTIOIV Conc3coPh~tl~p5 Planning Report -Geographic ----_-_-- .-,-_ Alaska Database: _EDM_2003.11_b48 Company; ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1 J-102 Design: 1J-102 (wp07) Planned Survey 1J-102 (wp07) MD Inclination Azimuth TVD (ft) (°) (°) lft) 6,007.90 85.00 182.00 3,756.64 Begin Build @ 4°/100' : 6008ft MD, 3757ft TVD 6,024.57 85.66 182.06 3,758.00 Sperry Elrilling Services Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 ND Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Map Map SSTVD +N/-S +E/-W Northing Easting (ft) (ft) (ft) (ft) (ft) 3,635.64 -1,390.57 1,855.97 5,944,680.89 560,628.29 3,637.00 -1,407.17 1,855.38 5,944,664.28 560,627.83 6,100.00 88.67 182.34 3,761.73 3,640.73 -1,482.44 6,184.46 92.03 182.66 3,761.21 3,640.21 -1,566.81 6,200.00 92.03 182.66 3,760.66 3,639.66 -1,582.32 6,300.00 92.03 182.66 3,757.12 3,636.12 -1,682.15 6,370.70 92.03 182.66 3,754.61 3,633.61 -1,752.73 Continue GeoSteer in Upper Lobe of A2 Sand, 6371ft MD, 3755ft TVD 6,400.00 91.53 181.60 3,753.70 3,632.70 -1,782.00 6,440.81 90.84 180.12 3,752.85 3,631.85 -1,822.79 6,500.00 90.84 180.12 3,751.99 3,630.99 -1,881.97 6,600.00 90.84 180.12 3,750.52 3,629.52 -1,981.96 6,700.00 90.84 180.12 3,749.05 3,628.05 -2,081.95 6,800.00 90.84 180.12 3,747.59 3,626.59 -2,181.94 6,900.00 90.84 180.12 3,746.12 3,625.12 -2,281.93 7,000.00 90.84 180.12 3,744.66 3,623.66 -2,381.92 7,100.00 90.84 180.12 3,743.19 3,622.19 -2,481.91 7,200.00 90.84 180.12 3,741.72 3,620.72 -2,581.90 7,300.00 90.84 180.12 3,740.26 3,619.26 -2,681.89 7,400.00 90.84 180.12 3,738.79 3,617.79 -2,781.88 7,500.00 90.84 180.12 3,737.33 3,616.33 -2,881.86 7,600.00 90.84 180.12 3,735.86 3,614.86 -2,981.85 7,700.00 90.84 180.12 3,734.39 3,613.39 -3,081.84 7,800.00 90.84 180.12 3,732.93 3,611.93 -3,181.83 7,900.00 90.84 180.12 3,731.46 3,610.46 -3,281.82 8,000.00 90.84 180.12 3,730.00 3,609.00 -3,381.81 8,100.00 90.84 180.12 3,728.53 3,607.53 -3,481.80 8,200.00 90.84 180.12 3,727.06 3,606.06 -3,581.79 8,300.00 90.84 180.12 3,725.60 3,604.60 -3,681.78 8,340.81 90.84 180.12 3,725.00 3,604.00 -3,722.59 1 J-102 T2 (wp07) 8,389.13 89.05 179.40 3,725.05 3,604.05 -3,770.90 8,400.00 89.05 179.40 3,725.23 3,604.23 -3,781.77 8,500.00 89.05 179.40 3,726.89 3,605.89 -3,881.75 8,600.00 89.05 179.40 3,728.55 3,607.55 -3,981.73 8,700.00 89.05 179.40 3,730.22 3,609.22 -4,081.71 8,800.00 89.05 179.40 3,731.88 3,610.88 -4,181.69 8,900.00 89.05 179.40 3,733.54 3,612.54 -4,281.67 9,000.00 89.05 179.40 3,735.20 3,614.20 -4,381.65 9,100.00 89.05 179.40 3,736.87 3,615.87 -4,481.63 9,128.26 89.05 179.40 3,737.34 3,616.34 -4,509.89 9,167.35 90.61 179.45 3,737.45 3,616.45 -4,548.97 9,200.00 90.61 179.45 3,737.10 3,616.10 -4,581.62 9,300.00 90.61 179.45 3,736.04 3,615.04 -4,681.61 9,400.00 90.61 179.45 3,734.98 3,613.98 -4,781.60 9,500.00 90.61 179.45 3,733.91 3,612.91 -4,881.59 DLSEV Vert Section (°l100ft) (ft) 0.00 1,390.57 4.00 1,407.17 1,852.48 5,944,589.00 560,625.52 4.00 1,482.44 1,848.80 5,944,504.62 560,622.49 4.00 1,566.81 1,848.08 5,944,489.10 560,621.89 0.00 1,582.32 1,843.44 5,944,389.25 560,618.03 0.00 1,682.15 1,840.16 5,944,318.65 560,615.31 0.00 1,752.73 1,839.07 5,944,289.38 560,614.45 4.00 1,782.00 1,838.46 5,944,248.58 560,614.15 4.00 1,822.79 1,838.34 5,944,189.41 560,614.49 0.00 1,881.97 1,838.13 5,944,089.43 560,615.06 0.00 1,981.96 1,837.92 5,943,989.45 560,615.63 0.00 2,081.95 1,837.71 5,943,889.48 560,616.20 0.00 2,181.94 1,837.50 5,943,789.50 560,616.77 0.00 2,281.93 1,837.29 5,943,689.52 560,617.35 0.00 2,381.92 1,837.08 5,943,589.54 560,617.92 0.00 2,481.91 1,836.87 5,943,489.56 560,618.49 0.00 2,581.90 1,836.66 5,943,389.59 560,619.06 0.00 2,681.89 1,836.45 5,943,289.61 560,619.63 0.00 2,781.88 1,836.24 5,943,189.63 560,620.20 0.00 2,881.86 1,836.03 5,943,089.65 560,620.77 0.00 2,981.85 1,835.82 5,942,989.67 560,621.34 0.00 3,081.84 1,835.62 5,942,889.70 560,621.91 0.00 3,181.83 1,835.41 5,942,789.72 560,622.48 0.00 3,281.82 1,835.20 5,942,689.74 560,623.05 0.00 3,381.81 1,834.99 5,942,589,76 560,623.63 0.00 3,481.80 1,834.78 5,942,489.78 560,624.20 0.00 3;581.79 1,834.57 5,942,389.80 560,624.77 0.00 3,681.78 1,834.48 5,942,349.00 560,625.00 0.00 3,722.59 1,834.69 5,942,300.69 560,625.58 4.00 3,770.90 1,834.80 5,942,289.83 560,625.78 0.00 3,781 .77 1,835.85 5,942,189.87 560,627.61 0.00 3,881 .75 1,836.90 5,942,089.91 560,629.44 0.00 3,981 .73 1,837.96 5,941,989.95 560,631.28 0.00 4,081 .71 1,839.01 5,941,889.99 560,633.11 0.00 4,181 .69 1,840.06 5,941,790.03 560,634.94 0.00 4,281 .67 1,841.11 5,941,690.07 560,636.77 0.00 4,381 .65 1,842.16 5,941,590.11 560,638.60 0.00 4,481 .63 1,842.46 5,941,561.86 560,639.12 0.00 4,509 .89 1,842.85 5,941,522.79 560,639.82 4.00 4,548 .97 1,843.17 5,941,490.14 560,640.39 0.00 4,581 .62 1,844.13 5,941,390.17 560,642.13 0.00 4,681 .61 1,845.09 5,941,290.20 560,643.87 0.00 4,781 .60 1,846.05 5,941,190.23 560,645.61 0.00 4,881 .59 5/20/2006 1:17:35PM Page 7 of 11 COMPASS 2003.11 Build 50 ~- ~ ~ ,~ ' • ~ ~- ~Ot14CO~l~~ p Halliburton Energy Servic Plan i R hi t G es HAL.L.EIRCIRTQN -~~~--P-~w~-~-~~~-~- ~--- ~ S n ng epor eograp - c ~ Sperry Drilling Services Database: _EDM_2003.11_b48 Local Go-ordin8te Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Mihimum Curvature Wellbor®: 1 J-102 Design: 1J-102 (wp07) Planned Survey 1J-102 (wp07) li Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ftl (ft) (ft) (ft) (°/1 ooftl (ft) 9,600.00 90.61 179.45 3,732.85 3,611.85 -4,981.58 1,847.01 5,941,090.26 560,647.35 0.00 4,981.58 9,700.00 90.61 179.45 3,731.78 3,610.78 -5,081.57 1,847.97 5,940,990.29 560,649.09 0.00 5,081.57 9,800.00 90.61 179.45 3,730.72 3,609.72 -5,181.56 1,848.93 5,940,890.33 560,650.83 0.00 5,181.56 9,867.35 90.61 179.45 3,730.00 3,609.00 -5,248.90 1,849.57 5,940,823.00 560,652.00 0.00 5,248.90 1 J-102 T3 (wp07) 9,900.00 89.31 179.38 3,730.02 3,609.02 -5,281.55 1,849.91 5,940,790.36 560,652.59 4.00 5,281.55 9,902.23 89.22 179.38 3,730.05 3,609.05 -5,283.78 1,849.93 5,940,788.12 560,652.63 4.00 5,283.78 10,000.00 89.22 179.38 3,731.39 3,610.39 -5,381.53 1,850.99 5,940,690.39 560,654.45 0.00 5,381.53 10,100.00 89.22 179.38 3,732.76 3,611.76 -5,481.52 1,852.08 5,940,590.43 560,656.32 0.00 5,481.52 10,200.00 89.22 179.38 3,734.13 3,613.13 -5,581.50 1,853.17 5,940,490.46 560,658.19 0.00 5,581.50 10,300.00 89.22 179.38 3,735.49 3,614.49 -5,681.49 1,854.25 5,940,390.50 560,660.06 0.00 5,681.49 10,400.00 89.22 179.38 3,736.86 3,615.86 -5,781.47 1,855.34 5,940,290.54 560,661.92 0.00 5,781.47 10,480.10 89.22 179.38 3,737.96 3,616.96 -5,861.56 1,856.21 5,940,210.47 560,663.42 0.00 5,861.56 10,500.00 89.98 179.59 3,738.10 3,617.10 -5,881.46 1,856.39 5,940,190.57 560,663.75 4.00 5,881.46 10,501.98 90.06 179.61 3,738.09 3,617.09 -5,883.44 1,856.40 5,940,188.59 560,663.78 4.00 5,883.44 10,600.00 90.06 179.61 3,737.99 3,616.99 -5,981.46 1,857.07 5,940,090.59 560,665.21 0.00 5,981.46 10,700.00 90.06 179.61 3,737.89 3,616.89 -6,081.45 1,857.75 5,939,990.61 560,666.67 0.00 6,081.45 10,800.00 90.06 179.61 3,737.78 3,616.78 -6,181.45 1,858.43 5,939,890.63 560,668.14 0.00 6,181.45 10,900.00 90.06 179.61 3,737.68 3,616.68 -6,281.45 1,859.11 5,939,790.65 560,669.60 0.00 6,281.45 11,000.00 90.06 179.61 3,737.57 3,616.57 -6,381.45 1,859.79 5,939,690.67 560,671.06 0.00 6,381.45 11,100.00 90.06 179.61 3,737.47 3,616.47 -6,481.44 1,860.48 5,939,590.69 560,672.52 0.00 6,481.44 11,200.00 90.06 179.61 3,737.36 3,616.36 -6,581.44 1,861.16 5,939,490.71 560,673.98 0.00 6,581.44 11,300.00 90.06 179.61 3,737.26 3,616.26 -6,681.44 1,861.84 5,939,390.73 560,675.44 0.00 6,681.44 11,400.00 90.06 179.61 3,737.15 3,616.15 -6,781.44 1,862.52 5,939,290.75 560,676.90 0.00 6,781.44 11,500.00 90.06 179.61 3,737.05 3,616.05 -6,881.44 1,863.20 5,939,190.77 560,678.36 0.00 6,881.44 11,600.00 90.06 179.61 3,736.94 3,615.94 -6,981.43 1,863.88 5,939,090.80 560,679.82 0.00 6,981.43 11,700.00 90.06 179.61 3,736.84 3,615.84 -7,081.43 1,864.56 5,938,990.82 560,681.28 0.00 7,081.43 11,800.00 90.06 179.61 3,736.74 3,615.74 -7,181.43 1,865.24 5,938,890.84 560,682.74 0.00 7,181.43 11,900.00 90.06 179.61 3,736.63 3,615.63 -7,281.43 1,865.92 5,938,790.86 560,684.21 0.00 7,281.43 12,000.00 90.06 179.61 3,736.53 3,615.53 -7,381.42 1,866.60 5,938,690.88 560,685.67 0.00 7,381.42 12,100.00 90.06 179.61 3,736.42 3,615.42 -7,481.42 1,867.28 5,938,590.90 560,687.13 0.00 7,481.42 12,200.00 90.06 179.61 3,736.32 3,615.32 -7,581.42 1,867.96 5,938,490.92 560,688.59 0.00 7,581.42 12,300.00 90.06 179.61 3,736.21 3,615.21 -7,681.42 1,868.64 5,938,390.94 560,690.05 0.00 7,681.42 12,400.00 90.06 179.61 3,736.11 3,615.11 -7,781.41 1,869.32 5,938,290.96 560,691.51 0.00. 7,781.41 12,500.00 90.06 179.61 3,736.00 3,615.00 -7,881.41 1,870.00 5,938,190.98 560,692.97 0.00 7,881.41 12,501.98 90.06 179.61 3,736.00 3,615.00 -7,883.39 1,870.02 5,938,189.00 560,693.00 0.00 7,883.39 1J-102 T4 (wp07) 12,514.97 90.39 179.82 3,735.95 3,614.95 -7,896.38 1,870.08 5,938,176.01 560,693.17 3.00 7,896.38 12,600.00 90.39 179.82 3,735.37 3,614.37 -7,981.41 1,870.35 5,938,091.00 560,694.10 0.00 7,981.41 12,700.00 90.39 179.82 3,734.70 3,613.70 -8,081.41 1,870.66 5,937,991.01 560,695.19 0.00 8,081.41 12,800.00 90.39 179.82 3,734.02 3,613.02 -8,181.40 1,870.98 5,937,891.03 560,696.28 0.00 8,181.40 12,900.00 90.39 179.82 3,733.34 3,612.34 -8,281.40 1,871.29 5,937,791.05 560,697.38 0.00 8,281.40 13,000.00 90.39 179.82 3,732.66 3,611.66 -8,381.40 1,871.60 5,937,691.07 560,698.47 0.00 8,381.40 13,100.00 90.39 179.82 3,731.99 3,610.99 -8,481.40 1,871.92 5,937,591.09 560,699.57 0.00 8,481.40 13,200.00 90.39 179.82 3,731.31 3,610.31 -8,581.39 1,872.23 5,937,491.10 560,700.66 0.00 8,581.39 13,300.00 90.39 179.82 3,730.63 3,609.63 -8,681.39 1,872.54 5,937,391.12 560,701.75 0.00 8,681.39 13,400.00 90.39 179.82 3,729.95 3,608.95 -8,781.39 1,872.86 5,937,291.14 560,702.85 0.00 8,781.39 13,500.00 90.39 179.82 3,729.28 3,608.28 -8,881.38 1,873.17 5,937,191.16 560,703.94 0.00 8,881.38 13,600.00 90.39 179.82 3,728.60 3,607.60 -8,981.38 1,873.49 5,937,091.18 560,705.04 0.00 8,981.38 50/2006 1:17:35PM Page 8 of 11 COMPASS 2003.11 Build 50 y F~ y " ~ Halliburton Energy Services C0110CClPf1tl~I~fS Planning Report -Geographic Alaska Database: _EDM_2003.11_b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1 J Pad Well: Plan 1J-102 Wellbore: 1 J-102 Design: 1J-102 (wp07) Planned Survey 1J-102 (wp07) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: WeIF Plan 1J-102 -Slot 1 J-102 Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) 1ft) (ft) (°/100ft) (ft) 13,688.19 90.39 179.82 3,728.00 3,607.00 -9,069.57 1,873.76 5,937,003.00 560,706.00 0.00 9,069.57 BHL @ 13588ft MD, 3728ft TVD : 3735ft FSL 8~ 581ft FEL - Sec11 - T10N - R10E - 41/2" -1J-102 T5 (Toe) {wp07) 5/20/2006 1:17:35PM Page 9 of 11 COMPASS 2003.11 Build 50 OR!GIN41_ MI.~..~r3ar-~TC~ tea sp.ny a.~~eirt9 services ~ ~ ~' ~ ~Qt'1C)CO~I~~1~335 Halliburton Energy Services HALl.1(BURT#aM Plannin R t G hi -------~--- ~~ g epor - eograp c Alaska Spwrn- E3-Nifrtg Services Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-102-Slot 1J-102 Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon 15 Plan cQ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-102 Design: 1J-102 (wp07) Geologic Targets 1J-102 TVD Target Name +N!-S +El-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,758.00 1J-102 Geo Poly (wp07) -1,363.08 1,859.89 5,944,708.41 560,631.99 - Polygon Point 1 -69.99 0.55 5,944,708.41 560,562.00 Point 2 -97.16 -404.70 5,944,303.00 560,538.00 Point 3 -116.66 -2,006.75 5,942,701.00 560,531.00 Point 4 -121.39 -3,508.91 5,941,199.00 560,538.00 Point 5 -133.14 -7,705.35 5,937,003.00 560,559.00 Point 6 162.88 -7,707.66 5,937,003.00 560,855.00 Point 7 93.64 -3,508.58 5,941,201.00 560,753.00 Point 8 69.34 -2,009.21 5,942,700.00 560,717.00 Point 9 57.80 -412.91 5,944,296.00 560,693.00 Point 10 73.01 -0.57 5,944,708.41 560,705.00 3,551.00 1J-102 T1 (D top) (wp07) -268.15 1,904.44 5,945,803.55 560,667.99 - Point 3,725.00 1J-102 DD Poly (wp07) -1,363.08 1,859.89 5,944,708.41 560,631.99 - Polygon Point 1 -50.00 0.39 5,944,708.41 560,581.99 Point 2 -50.18 -19.53 5,944,688.49 560,581.97 Point 3 -56.74 -195.07 5,944,512.92 560,576.78 Point 4 -68.51 -373.57 5,944,334.35 560,566.40 Point 5 -71.43 -459.38 5,944,248.53 560,564.15 Point 6 -75.41 -2,359.12 5,942,349.00 560,575.00 Point 7 -74.98 -2,451.76 5,942,256.38 560,576.15 Point 8 -70.89 -2,810.15 5,941,898.06 560,583.04 Point 9 -70.09 -2,885.52 5,941,822.71 560,584.43 Point 10 -60.32 -3,885.43 5,940,823.00 560,602.00 Point 11 -59.90 -3,925.63 5,940,782.81 560,602.73 Point 12 -53.77 -4,487.24 5,940,221.32 560,613.24 Point 13 -53.49 -4,519.99 5,940,188.57 560,613.78 Point 14 -39.87 -6,519.92 5,938,189.00 560,643.00 Point 15 -39.82 -6,530.83 5,938,178.10 560,643.14 Point 16 -36.13 -7,706.10 5,937,003.00 560,656.00 Point 17 63.88 -7,706.88 5,937,003.00 560,756.00 Point 18 60.19 -6,531.61 5,938,178.10 560,743.14 Point 19 60.13 -6,520.70 5,938,189.00 560,743.00 Point 20 46.52 -4,520.78 5,940,188.57 560,713.78 Point 21 46.23 -4,488.02 5,940,221.32 560,713.24 Point 22 40.11 -3,926.41 5,940,782.81 560,702.73 Point 23 39.69 -3,886.21 5,940,823.00 560,702.00 Point 24 29.92 -2,886.30 5,941,822.71 560,684.43 Point 25 29.12 -2,810.93 5,941,898.06 560,683.04 Point 26 25.02 -2,452.54 5,942,256.38 560,676.15 Point 27 24.60 -2,359.90 5,942,349.00 560,675.00 Point 28 28.57 -460.16 5,944,248.53 560,664.15 Point 29 31.49 -374.35 5,944,334.35 560,666.40 Point 30 43.27 -195.85 5,944,512.92 560,676.78 Point 31 49.83 -20.31 5,944,688.49 560,681.97 Point 32 50.00 -0.39 5,944,708.41 560,681.99 3,728.00 1J-102 T5 (Toe) (wp07) -9,069.57 1,873.76 5,937,003.00 560,706.00 - Point 3,730.00 1J-102 T3 (wp07) -5,248.90 1,849.57 5,940,823.00 560,652.00 - Point 3,725.00 1J-102 T2 (wp07) -3,722.59 1,834.48 5,942,349.00 560,625.00 - Point 5/20/2006 1:17:35PM Page 10 of 11 COMPASS 2003.11 Build 50 ~,I '~ ~. '' ~ Halliburton Energy Services • HALt~.tBURTG]N Cc~no-CC~111~5 Planning Report -Geographic ~-~~-~- ~----- Database: Alaska _EDM 2003.11 b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1 J-102 Design: 1J-102 (wp07) Spa:rry drilling Servresac Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 ND Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature 3,736.00 1J-102 T4 (wp07) -7,883.39 1,870.02 5,938,189.00 560,693.00 - Point Prognosed Casing Points ', Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ("? (") 120.00 120.00 20 20 2,645.82 2,243.00 10-3/4 13-1 /2 5,987.90 3,754.90 7-5/8 9-7/8 13,688.19 3,728.00 4-112 6-3/4 'I Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°1 (°) (ft) (ftl lftl Name 1,644.52 41.31 39.85 1,533.00 355.99 271.36 Base Perm 1,833.69 45.35 42.00 1,671.00 453.76 355.93 T3 2,246.77 45.04 64.21 1,962.00 629.18 588.66 K15 2,645.82 45.38 80.79 2,243.00 705.73 860.12 T3 + 550 3,690.24 45.94 126.94 2,987.00 644.07 1,563.71 Ugnu C 4,065.23 53.91 149.24 3,230.00 430.99 1,750.57 Ugnu B 4,209.74 57.96 156.46 3,311.00 324.52 1,804.97 Ugnu A 4,430.93 64.85 166.33 3,417.00 140.72 1,866.25 K13 4,865.07 77.00 180.00 3,551.00 -268.15 1,904.44 Wsak D 5,047.31 77.00 181.51 3,592.00 -445.70 1,902.10 WsakC 5,179.44 79.77 182.92 3,620.00 -574.71 1,897.26 Wsak B 5,392.44 80.00 183.00 3,657.00 -784.19 1,886.29 Wsak A4 5,570.97 80.00 183.00 3,688.00 -959.76 1,877.09 Wsak A3 5,948.18 83.44 182.31 3,750.90 -1,331.16 1,858.15 Wsak A2 5/20/2006 1:17:35PM Page 11 of 11 COMPASS 2003.11 Build 50 ~~~~~~ m. • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-102 1 J-102 1 J-102 (wp07) Anticollision Report 20 May, 2006 HALLIBURTQRI Sperry Qrlling Services ORIGINAL d o o ~ _ r F r o '_~ ?_ - - _ Z ~ Q c UQ `U M ~ F Erna qm o •a ~3, s 8 c mcU_-~ 3 ~ _ g ~ ~_ o C yU n~ '/ O /M i ~ ~ W O - ~ / O VI n ry n n U ~ .. w F y 0 ch /~ ~ ~ ~ ~ SL N ~ ~ / ` L ' ' w-w$'[~ % / r YSSSC<mee_$~SmRR''"'e 3,0 e.Fm~~n8m F8n8$°°'8C ~o£m'~ ,if ry °R~~°°°~3e°ggm3RY~&~^~~~<~Bm'amXe ~~ ° '~~vvw~v~ev~-^ ram„ m~~ "'8~8m~e $ W ~ °e ~ / w cs8sssms~omo~sss.pa.sgs~szs.3.s.xessa,oes, .u mw 3 / c ;> 8~ 3 8 a°8 8~°° 8 G ~°~° U y /~~ /. J y ~gO~n~o~a°a°o°n°u.o°v°a8°a°a°a°v°v°tig°go co (1 ~ ~. a w 388~~' S9 °=<m°'<mFw'38o~ w ~ ~ ~ ~ '«$ tea.°e~~338ffi'xx~mmmmmm3Ymmm6m O ch N N N 00 N F O 8g~:mmeoeYm,RN~v3B8.Cm~~~amam~S38, 8,F ~°°^"spa x°eee~x ssa~&s °~~~ma ~m~ r ~ __~~ 94 M '° F ~s888~8~s~'°FeR88Rgr83« R~°ososxe s $~g~6~6mmeg °~exeem4~~~~^.~~~~~~~~~~~ ~~ ti ~888s '° m8888888 0338 '°88° ~ ~<'a~:...«1~~~mSmmaaaxmmadmm8R88 ~- - F8o8R3~~S<a°~°°°6:+°.8a r~°a `m o ~' S8~$oe~~~~~~ar~gm a8~~~~~nemx ~~ ° °° ~°mm „ M ~ ~~ °~.+m ° n r Z N C N o 9 m ~ °~«.+au~onm °°~n.. a~nunma°_~.~ o v M r ~..r~aN e~.~w~«___««ryr~rrryr~n «.,~„~3 J ~ o Q m C b I J > 1~ J 3 9 u o~~ ~ O ~ c 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N U m ~ ~ M __ N 6 W vmi =~ O O ~ O~ O N~ !~ O N~ O O O O O O O O M N '^ 1~ ~ N rf1 I~ ~ ~ ~ ~ N N N C) O~ (O I~ m O ~ '- Q N Z o u V I I I I ~ I I I I~ I I ~~ 2a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ~ V~ O~ O~ O~ O~ O O O O O O g 0 0 N N I~ O ~~ I~ O N N 0 0 0 0 0 O O Q ~ ~ ~ N N N M V~ (O I~ W m O 38 m LL m r+ ~ = o t °i ~o ~ zo O +d Z o o r o ~ o 3 ^ iy _____________ •C O o, ;~ ~. e 3 ~.. o ... u M ~ N r 0 2omo + _ ~ ° M L ~ ~ ~ ~ A ~~~'~ ~ I z c~ %~ ~ ~' _ f ` O a o / ~ ~ -_~ _ ~ ~ r ~~'~~~ .~~- C ~ v ,~ { N ~ ~ ~ / ~ ''~-~ a ~ ~ o c ~ > i ~ rn ~- S o 0 -~. m .-, .., Q o' o' e °+ L + U _ ~ I: •-i _ _~. ~- c ~~ W ~ ~ ~ ~~ a y r o 0 8 h e ~ '~~ '-~ ~ ~ oo O O~ ~A ~'~ - r 7 S ~ ~+ / I ~ ~ ~~~ ~ ~ ~~wr I ~ ~ F G E f \ ~ ~ Q y' Z`~ c7 .< ~ . I'~ ~ fn 7 p ~ '~^ g'^ ~ C ~ ,, __ _ ,`. ?i C ~aoao 5 ~ ~ / -- - T ~ _~ ~ ~ 1 _ V ~ a'''te > 3 ~ / ~ ~ - A-`_ C $ 0..% i \ OD u0. dojo I ~~ W d C -' ~ ' 1 / ) I :C ~ d d d d~ az-j, ~ / ~~ ~ ~ I 1 \ ~ L W ..~ rTi x// / ^ F W LL'M1'LL'R' C I _ M ~ //. 1~ 1 ?» y ~ VI _- 'o I I 1 y~ w U -t~ O --_- r I 9.~ u 7 N ` ~ ~ N s 7 -_-- N d; m C -- ~ J OI O O O) N U r ~ C a '~ M • ConocoPhillips PJaska Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-102 Well Error: O.OOft Reference Welfbore 1J-102 Reference Design: 1J-102 (wp07) Halliburton Energy Services Af II~~ R rt HALLIBURTOIN n Ico Islon epo Spsrry Drilling Services Local Coordinate Reference: Well Plan 1J-102 -Slot 1J-102 TVD Reference: Doyon 15 Plan @ 121.OOft(Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: _EDM_2003.11 _b48 Offset TVD Reference: Reference Datum Reference 1J-102 (wp07) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,564.82ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma ~i Survey Tool Program Date 5/20/2006 From To (ft) (ft) Survey (Wellbore) 40.00 800.00 1J-102 (wp07) (1J-102) 800.00 13,888.19 1J-102 (wp07) (1J-102) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/20/2006 2:06:02PM Page 2 of 6 COMPASS 2003.11 Build 50 ~~~;~~~L .; ~6 LJ / Halliburton Energy Services ConocoPh illips Anticollision Report Alaska Company: ConocoPhillips Alaska Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1 J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1J-102 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-102 Database: Reference Design: 1J-102 (wp07) Offset ND Reference: • HQI_L[ BV RTON Sperry Drifting Services Well Plan 1 J-102 -Slot 1 J-102 Doyon 15 Plan ~ 12LOOft (Doyon 15 (81+40)) Doyon 18 PIar1 @ 121.OOft (Doyon 15 (81+40)) True Minimum Curvature 2.00 sigma _EDM_2003.11_b48 Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1 J Pad. 1 J-03 - 1 J-03 - 1 J-03 400.00 400.00 139.51 7.10 132.40 Pass -Major Risk 1 J-09 - 1 J-09 - 1 J-09 352.58 350.00 160.56 6.29 154.27 Pass -Major Risk 1J-101 - 1J-101 - 1J-101 663.33 650.00 26.49 14.21 12.28 Pass- Major Risk 1J-101 - 1 J-101 L1 - 1J-101 L1 663.33 650.00 26.49 14.21 12.28 Pass -Major Risk 1J-101 - 1J-101 L1 P61 - 1J-101 L1 PB1 663.33 650.00 26.49 14.21 12.28 Pass -Major Risk 1 J-101 - 1 J-101 L2 - 1 J-101 L2 663.33 650.00 26.49 14.21 12.28 Pass -Major Risk 1J-101-1J-101P61-1J-101P61 663.33 650.00 26.49 14.21 12.28 Pass-Major Risk 1J-14 - 1J-14 - 1J-14 7,347.70 4,650.00 870.34 134.64 758.13 Pass -Major Risk 1 J-152 - 1 J-152 - 1 J-152 359.01 350.00 148.37 7.60 140.77 Pass -Major Risk 1J-152 - 1J-152 L1 - 1J-152 L1 359.01 350.00 148.37 7.60 140.78 Pass -Major Risk 1 J-152 - 1 J-152 L2 - 1 J-152 L2 359.01 350.00 148.37 7.60 140.78 Pass -Major Risk 1J-152 - 1J-152 L2 P61 - 1J-152 L2 P61 359.01 350.00 148.37 7.60 140.78 Pass -Major Risk 1J-152 - 1J-152 P61 - 1J-152 P61 359.01 350.00 148.37 7.60 140.78 Pass -Major Risk 1 J-152 - 1 J-152 P62 - 1 J-152 P62 359.01 350.00 148.37 7.60 140.77 Pass -Major Risk 1 J-154 - 1 J-154 - 1 J-154 404.87 400.00 163.71 8.74 154.98 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 404.87 400.00 163.71 8.74 154.98 Pass -Major Risk 1 J-154 - 1 J-154 L2 - 1 J-154 L2 404.87 400.00 163.71 8.74 154.98 Pass -Major Risk 1 J-159 - 1 J-159 - 1 J-159 900.00 950.00 221.80 19.39 202.98 Pass -Major Risk 1 J-159 - 1 J-159 L1 - 1 J-159 L1 900.00 950.00 221.80 19.39 202.98 Pass -Major Risk 1J-159- 1J-159 L1 PB1 - 1J-159 L1 PB1 900.00 950.00 221.80 19.39 202.98 Pass- Major Risk 1 J-159 - 1 J-159 L1 PB2 - 1 J-159 L1 P62 900.00 950.00 221.80 19.39 202.98 Pass -Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 900.00 950.00 221.80 19.39 202.98 Pass -Major Risk 1J-159 - 1J-159 PB1 - 1J-159 PB1 900.00 950.00 221.80 19.39 202.98 Pass -Major Risk 1 J-164 - 1 J-164 - 1 J-164 354.43 350.00 334.59 7.64 326.95 Pass -Major Risk 1 J-164 - 1 J-164 L1 - 1 J-164 L1 354.43 350.00 334.59 7.64 326.95 Pass -Major Risk 1 J-164 - 1 J-164 L2 - 1 J-164 L2 354.43 350.00 334.59 7.64 326.95 Pass -Major Risk 1J-164 - 1J-164 L2 PB1 - 1J-164 L2 P61 354.43 350.00 334.59 7.64 326.95 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp07) 5,199.98 5,199.98 0.28 0.60 -0.32 FAIL - No Errors Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 (wp07) 4,899.98 4,900.00 0.97 0.60 0.37 Pass - No Errors Plan 1 J-103 - 1 J-103 - 1 J-103 (wp03) -North Heel 510.59 500.00 22.53 10.86 11.68 Pass -Major Risk Plan 1 J-103 - 1 J-103 L1 - 1 J-103 L1 (wp03) -North Hee 510.59 500.00 22.53 10.86 11.68 Pass -Major Risk Plan 1J-103 - 1J-103 L2 - 1J-103 L2 (wp03) -North Hee 510.59 500.00 22.53 10.86 11.68 Pass -Major Risk Plan 1 J-105 -Plan 1 J-105 - 1 J-105 (wp02) 360.83 350.00 60.58 7.60 52.99 Pass -Major Risk Plan 1 J-107 -Plan 1 J-107 - 1 J-107 (wp02) 360.09 350.00 100.57 7.58 92.98 Pass -Major Risk Plan 1 J-109 -Plan 1 J-109 - 1 J-109 (wp05) 347.59 350.00 160.44 7.46 152.98 Pass -Major Risk Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) 358.31 350.00 200.58 7.66 192.92 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 E Lateral - 1J 345.81 350.00 220.31 7.32 212.99 Pass -Major Risk Plan 1J-112 Kuparuk Prelim- 1J-12 Pilot- 1J-12 Pilot 345.81 350.00 220.31 7.32 212.99 Pass- Major Risk Plan 1J-112 Kuparuk Prelim -Plan 1J-12 W Lateral 345.81 350.00 220.31 7.32 212.99 Pass -Major Risk Plan 1 J-115 -Plan 1 J-115 - 1 J-115 (wp02) 356.95 350.00 280.52 7.53 272.99 Pass -Major Risk Plan 1 J-127 -Plan 1 J-127 - 1 J-127 (wp04) 3,794.29 4,099.98 148.83 58.97 92.04 Pass -Major Risk Plan 1J-127 -Plan 1 J-127 L1 - 1J-127 L1 (wp04) 3,794.29 4,099.98 148.83 79.17 70.51 Pass -Major Risk Plan 1J-127 -Plan 1J-127 L2 - 1J-127 L2 (wp04) 3,794,29 4,099.98 148.83 79.16 70.51 Pass -Major Risk Plan 1 J-133 - 1 J-133 - 1 J-133 (wp06) 341.58 350.00 640.83 7.30 633.53 Pass -Major Risk Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) 341.58 350.00 640.83 7.30 633.53 Pass -Major Risk Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) 351.84 350.00 680.58 6.61 673.97 Pass -Major Risk Plan 1J-136 - 1J-136 - 1 J-136 (wp04) 13,326.52 9,799.96 227.87 19.49 227.36 Pass -Minor 1/200 Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp04) 12,882.19 9,350.00 276.65 21.91 276.14 Pass -Minor 1/200 Plan 1 J-137 - 1 J-137 - J-137 (wp05) 13,650.15 9,850.00 941.32 322.14 627.20 Pass -Major Risk Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp05) 13,505.12 9,699.96 960.50 317.24 656.31 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDisposal 360.70 350.00 148.24 6.75 141.49 Pass -Major Risk Plan 1J-156 - 1J-156 - 1J-156 (wp05) 357.29 350.00 189.96 7.54 182.42 Pass -Major Risk CC -Min cenfre to center disfance or covergenf point, SF -min separation factor, ES -min ellipse separation 5/20/2006 2:06:02PM Page 4 of 6 COMPASS 2003.11 Build 50 OR161NAL • ConocoPhillips Alaska Company: ConocoPhillips Alaskalnc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-102 Well Error: O.OOft Reference Welibore 1J-102 Reference Design: 1J-102 (wp07) Halliburton Energy Services Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method; Output errors are at Database: Offset ND Reference: • HALLlBURTOl1~l Sperry Drilling Services Well Plan 1J-102 -Slot 1J-102 Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Doyon 15 Plan @ 121.OOft(Ooyo~ 15 (81+40)) True Minimum Curvature 2.00 sigma _EDM_2003.11_b48 Reference Datum Summary Site Name Offset Weli -Welibore -Design Kuparuk 1 J Pad Plan 1J-156- 1J-156 L1 - 1J-156 L1 (wp05) Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp05) Plan 1J-158 - 1J-158 - 1J-158 (wp03) WSP-02 -WSP-02 -WSP-02 WSP-03 -WSP-03 -WSP-03 WSP-15 -WSP-15 -WSP-15 WSP-1 S -WSP-1 S -WSP-1 S Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 357.29 350.00 189.96 357.29 350.00 189.96 357.54 350.00 217.55 351.55 350.00 185.10 408.74 400.00 245.18 396.33 400.00 126.59 550.88 550.00 73.31 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) 7.54 182.42 Pass -Major Risk 7.54 182.42 Pass -Major Risk 7.39 210.16 Pass -Major Risk 6.90 178.21 Pass -Major Risk 10.68 234.50 Pass -Major Risk 9.64 116.95 Pass -Major Risk 18.14 55.90 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/20/2006 2:06:02PM Page 5 of 6 COMPASS 2003.11 Build 50 .~~~~~!L • ~, ~r ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-102 -Slot 1J-102 1 J-102 Plan: 1J-102 (wp07) 1/4 Mile Scan 26 March, 2006 • A~. ~'" T Sperry Drifting Services ORIGINAL 625 0 I -125C I -187`. -3 c 0 N Z L O - Project: Kuparuk River Unit ----------------- - - - Site: Kuparuk 1J Pad \,1J o3 Well: Plan 1J-102 10 3/a'• Wellbore: 1 J-102 o Plan: 1J-102 (wp07) ^ti0 J OO a 5 ~~~ ~ T ~~im~t~s :~ ?°,;e rdorth Magnetic North: 24.04° WSP-03 ° Magnetic Field ~ " _ 175 Strength: 57564.1 nT " Dip Angle: 80.77° WSP-09 '181° ~~ Date: 7/1 /2006 Model: BGGM2005 I' I 'I -'~ WSP-13 I Shown are Existing wells which appear t .violate the 1320' radius surrounding the 1J-102 production Zone; WSP13, WSP11, WSP 9, WSP-3, 1J-14, 1 J-03, 1 J-159 Plan 1J-127 Could be drilled prior to the spud of the 1J-102. ~~ 1 WSP-11 180° J I~ I I I 1J-102 1/4 Mile @ Heel I I \ 7 5/8" I I I 180° I I I I ns° 179° i ~..° 0 N 179° ~ O Of 180° 1 -7 180° 1J-14 4 1/2" 1J-102 1/4 Mile @ Toe ~' r1ALLieuRTORI ConocoPhillips 9peny Drilling Ssnion A18Sk9 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 5000 5625 Closest in POOL ^~'y ~~"~`.J ~ J ~~ Closest A roach: Reference Well: 1J-102 Offset Well: 1J-159 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E(+ /W - 135.93° Comments De th Inci. An le TRUE Azi. ND E + AN - (135.93° Comments 1109.05 1 7000 90.94 180.12 3619.855 5943801 560617 2269.993 5575 89.43 185.75 3586.327 5943889 559511.9 2173.578 Closest A roach: Reference Well: 1J-102 Offset Well: 1J-127 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /y~ _) (135.93° Comments De th Incl. An le TRUE Azi. ND E +)/W - 135.93° Comments 4096.03 6092.03 85 180.5 3630.417 5944708 560632.2 1363.09 6449.64 83.1 359.82 3620.91 5948804 560608.6 -2732.924 Closest A roach: Reference Well: 1J-102 Offset Weil: 1J-03 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W _) 135.93° Comments De th Incl. An le TRUE Azi. ND E(+ /W - 135.93° Comments 4081.5 6092 85 180.5 3630.417 5944708 560632.2 1363.09 6450 64.69 62.27 3596.196 5948142 562864.7 -2052.855 Closest A roach: Reference Well: 1J-102 Offset Well: 1J-14 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - 135.93° Comments De th Incl. An le TRUE Azi. ND E + /W _ 135.93° Comments 2050.74 8725 88.27 179.35 3602.057 5942077 560630 3994.689 6850 68.93 126.96 3592.254 5942123 562680.2 3964.403 Closest A roach: Reference Well: 1J-102 Offset Well: WSP-13 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - 135.93° Comments De th Incl. An le TRUE Azi. ND E(+)/W _ 135.93° Comments 1320.81 6092 85 180.5 3630.417 5944708 560632.2 1363.09 3775 12.09 151.5 3629.67 5944988 559337.8 1073.236 Closes t A roa ch: Reference Well: 1J-102 Offset Well: WSP-11 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(- 135.93°) Depth Incl. Angle WSP-09 ND E(+)/W(-) (135.93°) Comments 1016.15 6092 85 180.5 3630.417 5944708 560632.2 1363.09 3900 16 107.9 3613.109 5945388 559861.9 677.634 Closest A roach: Reference Well: 1J-102 Offset Well: WSP-03 Coords - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. TVD E(+ /W - 135.93°) Comments De th Incl. Angle TRUE Azi. ND E + /W(- 135.93° Comments 1699.33 6092 85 180.5 3630.417 5944708 560632.2 1363.09 3800 15.66 98 3614.557 5945965 559470.5 96.83601 Closest A roach: Reference Well: 1J-102 Offset Well: WSP-09 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E(+)/W(-) (135.93°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(_) (135.93°) Comments 1434.73 6092 85 180.5 3630.417 5944708 560632.2 1363.09 3800 8.82 93.96 3619.845 5945469 559405.3 592.9344 POOLSummary1 3/26/2006 1:22 PM 1~-102 ~illina H (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Intermediate Hole Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-102 Drilling Hazards Summary 7/21/2006 3:48 PM Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/13/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 80' MD < Base of Permafrost at 1,643' MD (1,532' TVD) CemCADE~ Preliminary Job Design 10 3/4" Surface Casina on limited input data. For estimate purposes only. alum ~rg~ Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 30% excess below the permafrost. The top of the tail slurry is designed to be at 1,846' MD. Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (80') x 1.00 (no excess) = 51 ft3 0.3637 ft3/ft x (1643' - 80') x 3.50 (250°/d excess) = 1989.6 it3 0.3637 ft3/ft x (1846' - 1643') x 1.30 (30% excess) = 96 ft3 51 ft3 + 1989.6 ft3+ 96 ft3 = 21.36.6 ft3 2136.6 ft3 / 4.45 ft3/sk = 480.1 sks Round up to 490 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2646' - 1846') x 1.30 (30% excess) = 378.2 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 378.2 ft3 + 43.2 ft3 = 421.4 ft3 421.4 ft3/ 2.47 ft3/sk = 170.6 sks Round up to 180 sks BHST = 48°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll /minl < Top of Tail at 1,846' MD < 10 3/4", 68.0# casing in 13 1/2" OH TD at 2,646' MD (2,243' TVD) Mark of Schlumt~erger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 390.9 55.8 89.1 DeepCRETE 6.0 75.1 12.5 101.6 Drop top plug 0.0 0.0 5.0 106.6 Water 5.0 20.0 4.0 110.6 Switch to rig 0.0 0.0 5.0 115.6 Mud 7.0 217.8 31.1 146.7 Slow & bump plug 3.0 9.0 3.0 149.7 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint throughout tail slurry for proper cement placement. ~R161NAL CemCADE Prellminary Job Deslgn 7-5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/13/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 10 3/4", 68.0# casing at 2,646' MD < Top of Tail at 3,199' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 6,007 MD (3,756' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 2808' MD annular length Tail Slurrv Minimum thickening time: 175 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 2808' x 1.25 (25% excess) = 753.9 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 753.9 ft3 + 20.6 ft3 = 774.5 ft3 774.5 ft3/ 2.25 ft3/sk = 344.2 sks Round up to 350 sks BHST = 88°F, Estimated BHCT = 75°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) Ihhll (min) /mint CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 5.0 137.9 27.6 67.6 Drop. topplug 0.0 0.0 5.0 72.6 Wafer 5.0 20.0 4.0 76.6 Switch to rig 0.0 0.0 5.0 81.6 Mud 6.0 243.1 40.5 122.1 Slow & bump plug 3.0 9.0 3.0 125.1 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommendation -Tandem Rise Centralizers ~,es 2 on shoe track ~s.es 3 per 2 joints across the West Sak ~s,es 1 per joint across the Ugnu ORIGINAL .~/ y~ 20" 94.0# x 34" Insulated Conductor, K-55, set at +/- 80' 10-3/4" x 4-112" Wellhead, 5,000 psi 10-314", 68#, BTC ~~ Shoe set @ 2646' MD, 2243' TVD / Tubing String 4-112" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 5112" X 7-518" ZXP Liner Top Packer wl Hold Seal Assembly Downs 4.75" Seal OD Tubing, 4.1/2", 12.6#, IBTM, Special Drift to +l- 500' 3.875" DB Nipple, for Possible SSSV, +/- 500' GLM, Camco KBG-2, 4-112" X 1", 25 deg, 1,200 ft MD GLM, Camco KBG-2, 4-1/2" X 1 ", 70 deg, +/- 1 jt above sliding sleeve CMD Sliding Sleeve, w/ 3.81" DB Nipple, 72 deg, +l- 1 jt above seals Casing Sealbore Receptacle, 20' Length Lateral Entry Module(LEM) D-sand Window t 4865' MD, 3551' ND 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint ConocoP'hillips West Sak 7-5/8" Injector 1J-102 Tri-Lateral Completion 'D' Sand Lateral Bent Joint 3-112" Guide Shoe 4-1/2" Liner Shoe, 11.6#, L-80 BTC Set ~ 12187' MD, 3509' TVD 4-112" X 7-518" Seal Bores Model'B' HOOK Hanger 3.68" ID 5-112" X 7-518" ZXP Liner Top Packer wl Hold Downs Lateral Entry Module ILEM) Assembly f~ 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Profile ./ Automatic Alignment of LEM Positive Latching Collet ~~ Indicates Correct Location Seal Bore for Lateral Isolation - 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbore Receptacle 20' Length Seal Assembly 4.75" Seal OD Lateral Entry Module(LEM) B-sand Window at 5185' MD, 3621' ND Liner Swivel 4112" X 7-518" - Model'B' HOOK Hanger Seal Bores 3.68" ID 4-112" 12.6# Tubin 3.833" Drift 3.958" ID / 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs 5-112" X Liner Hanger) Packer Assembly at FIexL Liner H +1- 5300' MD 'B' Sand Lateral 4-112" 11.6# L-80 Slotted Liner Every Other Joint / 3-112" Bent Joint I + ,.. / _ 3-112" Guide Shoe 3.562" DB Nipple Sealbore Receptacle, 20' Length ® Baker Hughes 2005. This doe ent may no[ be reproduced or tllshlbutetl, In whole or in part, In any form or by any means elecbonlc or mechanical, inclutling photocopying, recortling, or by any Information storage and retrieval system now known or hereaRer invented, without written txrmisslon hom Baker Hughes Inc. As Planned r... BAKER NYGNES Baker Oil 9'ools With Dive rters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool Skiing Installed Installed (3.00" Lateral Drill) Iz.so° ID Mainbore Drift) 'G5; Profile for Coil Connector f Running/Retrieving \ ; ' (1.00' Length) I Snap INSnap Out ~ .~ Positive Locating ti r Back Preaswe Valve I Collet (1.60' Length) i I Lateral Isolation ~~ r Flaw-Thru Swivel Seals I, I (1.25' Length) f Lateral Diverter I / Hydraulic Ramp ~ Disconnect Isolation/ Mainbore (1.50' Length) Diverter Sleeve ~/ GS Spear ' ~~ Lateral lsolatlon (1.50 Length) i ~ Seals 6.85 R Approx. OAL' :, I -Jars may be required in highly deviated 1g.5' Diverter Length 18.5' Sleeve Length or deep applications (6' approz length). 4-1/2" Liner Shoe, 11.6#, L-80 BTC Set ~ 12492' MD, 3582' TVD Seal Assembly I~ ... "~ 4.75" Seal OD 'A' Sand Undulating Lateral 4-112" 11.6# L-80 Slotted Liner Every Other Joint 4-112" Eccentric / .Guide Shoe 7-5/8" 40# Casing, L-80, BTCli11 Set at ~ 5988' MD, 3755' TVD (84 deg) Equipment Specifications 4-112" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-112" Lateral Entry Module Mainbore Drift: 3.65" ainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +I- 3.89" Diverter and Sleeve Length: +l- 18.5' 4-1/2" Casing Shoe, 11.6#, K-80 BTC Set @ 13688' MD, 37 TVD • • • SHARON K. ALLSUP-DRAKE ~~ CONOCOPHILLIPS 1151 ATO 1530 700 G ST. ~ ANCHORAGE AK 99501 '^ DATE ~ ~- ~'~~61551/441 PAY TO THE S~~Tt~d~ /Li ,/1~ ORDER OF '`!` /r l C._~~ ~- r~~^-7C'C Q /v~ ~~ /' J+ DOLLARS LJ ~,:~,~,a,n, JPMorganChase ~~ JPMorgan Chase Bank, N.A. r Valid Up To 5000 Dollars Columbus, OH ~~ / ~/~ MEMO ~~ -- -- L-~-'~ -- ~:044~155L1~:5 28 74 7 190 79 2 7n'115i ~. • TRANSMITTAL LETTER CHECKLIST WELL NAME ,~~G~ ~ ~ /D Z.,, PTD# ZO(o ~ ~~+~ Development `/Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing wel l (If last two digits in permit No. API No. 50- - - API number are , between 60-69) j Production should continue to be reported as a function of the original API number stated above. i PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the j liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C : \j ody\transmittal_checkl ist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOlL-490150 Well Name: KUPARUK RIV U WSAK 1J-102 Program SER Well bore seg ^ PTD#:2061100 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER / PEND GeoArea 890 Unit 11160 On/Off Share On Annular Disposal ^ Administration 1 Permit_fee attached. - - - - _ - . _ _ _ - _ ...... Yes _ _ _ - - - -West Sak A sand.injector. Main well bore for a tri-later_al_ injection well. 2 Lease number appropriate- - - Yes - - - -Surface an_d top production interval located. in ADL 25661;-TD-in ADL 25662._ _ - - - - - - - - - - - - - - - - - - - - 3 Uniquewell_nameandnumber_____________________________ ________ Yes...... ..._._.._...._--.-_. ---------------------------------------------- 4 Well located in-adefinedpool______---____________________ __ ______Yes______ _KuparukRiver,West_SakOilPool-490150,-governed.byC0406B--__----_____--.--_----__-_ 5 Well located proper distance from drilling unitboundary---- - - - - - - - - - - Yes - Well is more than. 500 feet from an external property line.. - - .. - .. - . - _ ....... - - - . . 6 Well lorzted proper distance from other wells- - - _ ...... - -Yes .. - - - - - GO 4066, Rule 3:_ no restrictions as to well spacing exce t that no- a shall be o _ened in a well closer - p pY p 7 Sufficient acreage available in drilling unit- - - - - - - - - - - - - - Yes than 500 feel to_an external_prope[ty1ine where ownership. or landownership changes, - _ _ - - _ _ _ . - - - - - - 8 If deviated, is_wellbore plat-included - - - Yes - - - - 9 Ope[atoronlyaffectedparty____--------------__ _______ _______-_Yes______ _______-__ 10 Ope[atorhas_approprlate.bond(nforcfl-- ------------ ------- - -- --Yes ----- - ~-- ..............----------...-~ ------------ -- ------ 11 Pe[mitcanbeissuedwithoutco_nservationgrder----------------__ _-____ _-Yes-_____ ______________-_____---__--____ ___-______-_-_--.---.-------.---.__- Appr Date 12 Pe[mit.eanbeissuedwithoutadministrative-approval---------------- ----__ Yes______ _---__________-_--____-__--___._--___-_________.--_.-_.--__----_- SFD 7!2712006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by Injection Order # (put_10# in_comments)_(For_ Yes Area Injection Order No,26 _ _ _ _ _ _ - - - - 15 All wells within 1!4_mile area_of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - - - -WSP-3, WSP-9, WSPc11, WSP-13,-KRU 1J-159 and late[als_ _ _ _ . _ _ _ . _ - _ _ .... _ ... - - _ . - _ - - _ - - 16 Pre-produced injector; duration of pre production less than 3 months_(For service well only) - Yes - - - - - KRU 1J-Pad injection wells are_typiczllypve-produced 30-45 days for cleanup.. 17 Nonconven, gas conforms to AS31,05,030Q.1.A),O.2.A-l)) - - - - - - - - - - - - - _ - NA- _ - - _ _ Engineering 18 Conductor string-provided----------------------------_-- -__--__-_Yes_____ -__ 19 Surface casing-protects all known U$DWs ..................... _- --_-- NA____ Allaquifersexempted,40CFR-147.102(b)(3).-_--_--__--__-__-_------,-_-_-________ 20 CMT.vo(adeguate-to ci[cul_ate on conducto[& su_rfcsg - - _ _ _ - - - - - - - - - - - - - - - -Yes _ _ _ _ _ - - - _ . ----------------------------------------------------------------- 21 CMT-vol adequate-to tie-in long string to surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - - -N_o_ _ _ _ - _ _ _ All hydrocarbons to-be_covered. Annular disposal may-be-proposed, _ _ - _ _ - - - - - , _ - - - - _ - _ _ - - - _ - - - 22 CMT.willcoyerallknown_productivehorizons____________________ _________No-__-__- -Slottedlinercompletion planned._______________-_-_____________ 23 Casing designs adequate for G,TB&_permafrost________ _--- Yes------ -------------------------------- ----------------,----------_-_ -- 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - -- Yes _ _ _ _ _ - -Rig isequipped with steel-pits.. No reserve-pitplanned, All waste to approved annulus or disposal wel_l.- - _ _ _ _ 25 Ifa-re-drill,has_a_1.0-403 for abandonment been approved----_.______ _________ NA_______ _________________-_--.- 26 Adequate wellbore separaiionproposed _ _ _ _ _ _ _ _ _ __ _ _ _ _ __ _ _ _ _ __ _ _ _ _ __ _ _ _ _Yes _ - _ - _ - -Proximity analysis performed, Traveling cylinder path calculated: Gyros possible, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . 27 If_diverterrequired,doesjtmeetregulations_____________________ -___--.-Yes------ ___.__--______--_- -------------------------------------------------- Appr Date 28 Drilling fluid_prpgram schematic $ equip list adequate- Yes - - - - - Maximum expected f_o[mation pressure 8,7_EMW._ Planned MW 8.6ppg or_as needed-- - - - - - - - - - - - - TEM 8!2!2006 29 BOPEs,dotheymeetregulation--_------------------------ --- -----Yes----- ----------------------------.-------------------------------- - ~„r/~ ` 30 BOPE_press rating appropriate; test to_(put prig in comments)- - - - - - - - - - - - - - - - - - - -Yes - _ . _ - - - MA$P caleulatedat 1278psi. 3K stack arrangement and BOP_test plann_ed._ _ _ - _ _ _ - _ - - - _ - ~~~ 31 Choke_manifoldcomplieswlAPl_RP-53 (May 84)---_____ Yes_____ ________________________________________ VVV 32 Workwrlloccu[wrthoutoperahonshutdown_____________________ _________Yes__-___ _____-_-____________-_____-___-_-__--____ 33 Is presence-of H2S gas-probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No- _ _ _ _ _ _ _H2S has not_been [eportedat 1J_pad.- Rig isequippedwith sensors and alarms, - - - . - - _ _ _ _ - . _ _ - - - _ - 34 Mechanical condition of wells within AQR verified (Forservice well onlya _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ - _ _ - -File reviews indicate 1J-159 is satisfactorily cemented and the WSP wells satisfactorily-abandoned. - - - - .... . Geology 35 Permitcan be issued wlo hydrogen_sul_fidemeasvres - - - - - - - - - - - - - - - - - - - - -Yes _ _ - _ _ - _ No H2S has been measured in_W Sak wells drilled south from 1J-Pad. Rig has sensors and_alarms.- _ _ - . - _ - _ 36 Data-presented on potential overpressure zones Yes - - - - Expected res._pre_ssure is -8.7ppg EMW, will be drilled with 8.6 ppg oil-based mud. Mud weight will be _ - _ - Appr Date 37 Seismic_analysis ofshallow gas-zones- - - - - - - - - - - - - - - - ----- - - - - - - - - - - - - NA- - - - - adjusted as needed. _ No shallow_gas expected..... - ...... - - -- SFD 7/27/2006 38 Seabedcgndjtionsuryey_(ifoffshore)__ ______________________ _________ NA-___ -Mud program notes use of 9.6 ppg mud if hydrates are_encountered, _ - _ _ - 39 Contact namelphone for weekly_progress reports_[exploratoryOn1y] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ Geologic Commissioner: Engineering Public Date: Co missioner: Date 'oner West Sak A sand in ector. This well will the the main well bore for a tri-lateral in ection well. SFD Date ~ 1 • • 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 it~e Well History file and to simplify finding iniomiation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun DriZ'ling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 03 07:28:53 2006 Reel Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF • Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1J-102 API NUMBER: 500292331700 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 03-NOV-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 5 JOB NUMBER: MW0004559176 MW0004559176 MW0004559176 LOGGING ENGINEER: B. HENNINGSE B. HENNINGSE O. OBI OPERATOR WITNESS: M. THORNTON M. THORNTON M. THORNTON MWD RUN 6 JOB NUMBER: MW0004559176 LOGGING ENGINEER: O. OBI OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 35 11N l0E 2245 2446 121.30 81.00 CASING DRILLERS ~~"~ ( I ~Ha~s BIT S~ (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) • 10.750 2642.0 7.625 5920.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-102 PB3 WELLBORE AT 9210'MD/3739'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,5,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,5,6 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5,6 REPRESENT WELL 1J-102 WITH API#: 50-029-23317-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11025'MD/3768'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2606.0 10967.5 RPD 2630.0 10974.5 RPS 2630.0 10974.5 RPM 2630.0 10974.5 FET 2630.0 10974.5 RPX 2630.0 10974.5 ROP 2652.5 11025.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2606.0 5926.0 3 5926.0 7600.0 5 7600.5 9210.0 6 9210.5 11025.0 REMARKS: MERGED MAIN 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 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 11025 6815.5 16839 2606 11025 RPD MWD OHMM 0.47 2000 22.2123 16690 2630 10974.5 RPM MWD OHMM 1.54 2000 15.3291 16690 2630 10974.5 RPS MWD OHMM 2.05 2000 12.9738 16690 2630 10974.5 RPX MWD OHMM 2.11 125.86 11.7227 16690 2630 10974.5 FET MWD HOUR 0.14 83.37 1.59343 16690 2630 10974.5 GR MWD API 20.76 126.62 72.3612 16724 2606 .10967.5 ROP MWD FT/H 1.65 1098.43 193.813 16746 2652.5 11025 First Reading For Entire File..........2606 Last Reading For Entire File...........11025 Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLTB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2606.0 5879.0 RPD 2630.0 5871.5 RPM 2630.0 5871.5 RPX 2630.0 5871.5 RPS 2630.0 5871.5 FET 2630.0 5871.5 ROP 2652.5 5926.0 LOG HEADER DATA DATE LOGGED: 31-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5926.0 TOP LOG INTERVAL (FT) 2652.0 BOTTOM LOG INTERVAL (FT) 5926.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.9 MAXIMUM ANGLE: 82.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2642.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) ~ 58.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.500 84.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.140 113.0 MUD FILTRATE AT MT: 1.650 84.0 MUD CAKE AT MT: 1.800 84.0 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 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 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max .Mean Nsam Reading Reading DEPT FT 2606 5926 4266 6641 2606 5926 RPD MWD020 OHMM 1.26 2000 20.6338 6484 2630 5871.5 RPM MWD020 OHMM 1.54 1743.45 14.2604 6484 2630 5871.5 RPS MWD020 OHMM 2.05 129.28 11.5957 6484 2630 5871.5 RPX MWD020 OHMM 2.11 62.61 9.96614 6484 2630 5871.5 FET MWD020 HOUR 0.14 81.01 1.20528 6484 2630 5871.5 GR MWD020 API 20.76 126.62 68.3394 6547 2606 5879 ROP MWD020 FT/H 2.98 1098.43 202.148 6548 2652.5 5926 First Reading For Entire File..........2606 Last Reading For Entire File...........5926 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/i1f03 Maximum Physical Record..65535 File Type ................LO Next File Name..........~SLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5872.0 7600.0 FET 5872.0 7600.0 RPM 5872.0 7600.0 RPD 5872.0 7600.0 RPS 5872.0 7600.0 GR 5879.5 7600.0 ROP 5926.5 7600.0 LOG HEADER DATA DATE LOGGED: 05-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7600.0 TOP LOG INTERVAL (FT) 5926.0 BOTTOM LOG INTERVAL (FT) 7600.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 65.0 MUD PH: .0 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 114.8 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 Depth Units ....................... Datum Specification Block sub-type...0 000 ~o 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5872 7600 6736 3457 5872 7600 RPD MWD030 OHMM 0.47 2000 46.7379 3457 5872 7600 RPM MWD030 OHMM 2.86 2000 24.3659 3457 5872 7600 RPS MWD030 OHMM 5.51 2000 18.0961 3457 5872 7600 RPX MWD030 OHMM 5.35 1 25.86 15.9707 3457 5872 7600 FET MWD030 HOUR 0.14 83.37 3.1851 3457 5872 7600 GR MWD030 API 43.65 117.9 76.1091 3442 5879.5 7600 ROP MWD030 FT/H 1.65 4 16.42 246.205 3348 5926.5 7600 First Reading For Entire File..........5872 Last Reading For Entire File...........7600 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name............~SLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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 RPS 7600.5 9210.0 FET 7600.5 9210.0 RPM 7600.5 9210.0 RPX 7600.5 9210.0 GR 7600.5 9210.0 RPD 7600.5 9210.0 ROP 7600.5 9210.0 LOG HEADER DATA DATE LOGGED: 08-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9210.0 TOP LOG INTERVAL (FT) 7600.0 BOTTOM LOG INTERVAL (FT) 9210.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 64.0 MUD PH: .0 MUD CHLORIDES (PPM): 19500 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 119.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 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 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7600.5 9210 8405.25 3220 7600.5 9210 RPD MWD050 OHMM 4.94 27.89 13.5922 3220 7600.5 9210 RPM MWD050 OHMM 4.93 36.76 14.5109 3220 7600.5 9210 RPS MWD050 OHMM 4.95 37.92 14.5929 3220 7600.5 9210 RPX MWD050 OHMM 4.74 37.24 14.0419 3220 7600.5 9210 FET MWD050 HOUR 0.25 59.65 1.59412 3220 7600.5 9210 GR MWD050 API 45.1 105.9 71.2395 3220 7600.5 9210 ROP MWD050 FT/H 6.16 410.88 165.691 3220 7600.5 9210 First Reading For Entire File..........7600.5 Last Reading For Entire File...........9210 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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.......06/11/03 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 SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 9210.5 10974.5 ROP 9210.5 11025.0 RPX 9210.5 10974.5 RPS 9210.5 10974.5 RPD 9210.5 10974.5 GR 9210.5 10967.5 FET 9210.5 10974.5 LOG HEADER DATA DATE LOGGED: 09-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11025.0 TOP LOG INTERVAL (FT) 9210.0 BOTTOM LOG INTERVAL (FT) 11025.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 97.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 66.0 MUD PH: .0 MUD CHLORIDES (PPM): 19000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 124.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: r Data Format Specification R~rd 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 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 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9210.5 11025 10117.8 3630 9210.5 11025 RPD MWD060 OHMM 4.59 19.62 8.9528 3529 9210.5 10974.5 RPM MWD060 OHMM 4.47 21.21 9.18684 3529 9210.5 10974.5 RPS MWD060 OHMM 4.18 21.61 9.01084 3529 9210.5 10974.5 RPX MWD060 OHMM 3.64 21.33 8.67277 3529 9210.5 10974.5 FET MWD060 HOUR 0.26 11.22 0.746789 3529 9210.5 10974.5 GR MWD060 API 53.11 112.78 77.2099 3515 9210.5 10967.5 ROP MWD060 FT/H 8.51 345.23 155.399 3630 9210.5 11025 First Reading For Entire File..........9210.5 Last Reading For Entire File...........11025 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Scientific Technical Services Next Reel Name..........~KNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services End Of LIS File Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Oct 31 16:16:24 2006 Reel Header Service name .............LISTPE Date .....................06/10/31 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/10/31 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004559176 B. HENNINGSE M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP:. RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING • Scientific Technical Services Scientific Technical Services 1J-102PB1 500292331770 ConocoPhillips Alaska, Inc. Sperry Drilling Services 31-OCT-06 MWD RUN 3 MW0004559176 B. HENNINGSE M. THORNTON 35 11N l0E 2245 2446 121.30 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2642.0 7.625 5920.0 ~blo'1~O ~ l~l ark REMARKS: • • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 1J-102 PBl WITH API#: 50-029-23317-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8159'MD/3732'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/3I 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; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2606.0 8101.5 RPD 2630.0 8108.5 FET 2630.0 8108.5 RPS 2630.0 8108.5 RPM 2630.0 8108.5 RPX 2630.0 8108.5 ROP 2652.5 8159.0 BASELINE CURVE FOR SHIFTS: • CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2606.0 5926.0 MWD 3 5926.0 8159.0 REMARKS: MERGED MAIN 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 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 8159 5382.5 11107 2606 8159 RPD MWD OHMM 0.47 2000 27.9325 10958 2630 8108.5 RPM MWD OHMM 1.54 .2000 17.1197 10958 2630 8108.5 RPS MWD OHMM 2.05 2000 13.5519 10958 2630 8108.5 RPX MWD OHMM 2.11 125.86 11.9022 10958 2630 8108.5 FET MWD HOUR 0.14 83.37 1.75015 10958 2630 8108.5 GR MWD API 20.76 127.44 73.1307 10992 2606 810.1.5 ROP MWD FT/H 1.65 1098.43 222.015 11014 2652.5 8159 First Reading For Entire File..........2606 Last Reading For Entire File...........8159 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/31 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.......06/10/31 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2606.0 5879.0 FET 2630.0 5871.5 RPX 2630.0 5871.5 RPS 2630.0 5871.5 RPM 2630.0 5871.5 RPD 2630.0 5871.5 ROP 2652.5 5926.0 LOG HEADER DATA DATE LOGGED: 31-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5926.0 TOP LOG INTERVAL (FT) 2652.0 BOTTOM LOG INTERVAL (FT) 5926.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.9 MAXIMUM ANGLE: 82.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 2642.0 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: Fresh Water Gel 9.10 58.0 9.1 450 4.4 1.500 84.0 1.140 113.0 1.650 84.0 1.800 84.0 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 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 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 5926 4266 6641 2606 5926 RPD MWD020 OHMM 1.26 2000 20.6338 6484 2630 5871.5 RPM MWD020 OHMM 1.54 1743.45 14.2604 6484 2630 5871.5 RPS MWD020 OHMM 2.05 129.28 11.5957 6484 2630 5871.5 RPX MWD020 OHMM 2.11 62.61 9.96614 6484 2630 5871.5 FET MWD020 HOUR 0.14 81.01 1.20528 6484 2630 5871.5 GR MWD020 API 20.76 126.62 68.3394 6547 2606 5879 ROP MWD020 FT/H 2.98 1098.43 202.148 6548 2652.5 5926 First Reading For Entire File..........2606 Last Reading For Entire File...........5926 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/31 Maximum Physical Record..65535 File Type ................L0 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.......06/10/31 Maximum Physical Record..65535 File Type ................L0 Previous File Name......~LIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5872.0 8108.5 RPD 5872.0 8108.5 RPM 5872.0 8108.5 FET 5872.0 8108.5 RPS 5872.0 8108.5 GR 5879.5 8101.5 ROP 5926.5 8159.0 LOG HEADER DATA DATE LOGGED: 05-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8159.0 TOP LOG INTERVAL (FT) 5926.0 BOTTOM LOG INTERVAL (FT) 8159.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 65.0 MUD PH: .0 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 114.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 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 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5872 8159 7015.5 4575 5872 8159 RPD MWD030 OHMM 0.47 2000 38.5103 4474 5872 8108.5 RPM MWD030 OHMM 2.86 2000 21.2637 4474 5872 8108.5 RPS MWD030 OHMM 5.21 2000 16.387 4474 5872 8108.5 RPX MWD030 OHMM 4.95 125.86 14.7082 4474 5872 8108.5 FET MWD030 HOUR 0.14 83.37 2..53981 4474 5872 8108.5 GR MWD030 API 43.65 127.44 80.1877 4445 5879.5 8101.5 ROP MWD030 FT/H 1.65 480.31 251.142 4466 5926.5 8159 First Reading For Entire File..........5872 Last Reading For Entire File...........8159 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/10/31 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/10/31 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Library. Scientific Technical Services Service name .............LISTPE Date .....................06/10/31 Origin ...................STS Reel Name ................UNKNOWN Continuation Number..... • Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 03 08:49:27 2006 Reel Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004559176 B. HENNINGSE M. THORNTON • Scientific Technical Services Scientific Technical Services 1J-102PB2 500292331771 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-NOV-06 MWD RUN 3 MWD RUN 4 MW0004559176 MW0004559176 B. HENNINGSE O. OBI M. THORNTON M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 35 11N l0E 2245 2446 121.30 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 2642.0 6.750 7.625 5920.0 ~O~fJ~d~~ REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-102 PB1 WELLBORE AT 7710'MD/3735'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4 REPRESENT WELL 1J-102 PB2 WITH API#: 50-029-23317-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8401'MD/3740'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2606.0 8343.5 FET 2630.0 8350.5 RPD 2630.0 8350.5 RPS 2630.0 8350.5 RPM 2630.0 8350.5 RPX 2630. 8350.5 ROP 2652.5 8401.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2606.0 5926.0 MWD 3 5926.0 7710.0 MWD 4 7710.5 8401.0 REMARKS: MERGED MAIN 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 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 8401 5503.5 11591 2606 8401 RPD MWD OHMM 0.47 2000 28.3934 11442 2630 8350.5 RPM MWD OHMM 1.54 2000 18.1179 11442 2630 8350.5 RPS MWD OHMM 2.05 2000 14.7319 11442 2630 8350.5 RPX MWD OHMM 2.11 2000 13.1365 11442 2630 8350.5 FET MWD HOUR 0.14 83.37 1.71898 11442 2630 8350.5 GR MWD API 20.76 1 26.62 71.996 11476 2606 8343.5 ROP MWD FT/H 0.63 10 98.43 222.523 11498 2652.5 8401 First Reading For Entire File..........2606 Last Reading For Entire File...........8401 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2606.0 5879.0 FET 2630.0 5871.5 RPX 2630.0 5871.5 RPS 2630.0 5871.5 RPM 2630.0 5871.5 RPD 2630.0 5871.5 ROP 2652.5 5926.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 31-AUG-06 Insite 72.13 Memory 5926.0 2652.0 5926.0 39.9 82.9 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 e for each bit run in separate files. 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: 9.875 2642.0 Fresh Water Gel 9.10 58.0 9.1 450 4.4 1.500 84.0 1.140 113.0 1.650 84.0 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 .12N Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 1.800 ~0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 5926 4266 6641 2606 5926 RPD MWD020 OHMM 1.26 2000 20.6338 6484 2630 5871.5 RPM MWD020 OHMM 1.54 1743.45 14.2604 6484 2630 5871.5 RPS MWD020 OHMM 2.05 129.28 11.5957 6484 2630 5871.5 RPX MWD020 OHMM 2.11 62.61 9.96614 6484 2630 5871.5 FET MWD020 HOUR 0.14 51.01 1.20528 6484 2630 5871.5 GR MWD020 API 20.76 126.62 68.3394 6547 2606 5879 ROP MWD020 FT/H 2.98 1098.43 202.148 6548 2652.5 5926 First Reading For Entire File..........2606 Last Reading For Entire File...........5926 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5872.0 7710.0 RPS 5872.0 7710.0 RPX 5872.0 7710.0 RPM 5872.0 7710.0 RPD 5872.0 7710.0 GR 5879.5 7710.0 ROP 5926.5 7710.0 LOG HEADER DATA DATE LOGGED: 05-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7710.0 TOP LOG INTERVAL (FT) 5926.0 BOTTOM LOG INTERVAL (FT) 7710.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 65.0 MUD PH: .0 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 114.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 .................Dowr1 Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET. MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5872 7710 6791 3677 5872 7710 RPD MWD030 OHMM 0.47 2000 45.0902 3677 5872 7710 RPM MWD030 OHMM 2.86 2000 24.135 3677 5872 7710 RPS MWD030 OHMM 5.51 2000 18.2671 3677 5872 7710 RPX MWD030 OHMM 5.35 1 25.86 16.2617 3677 5872 7710 FET MWD030 HOUR 0.14 83.37 3.01495 3677 5872 7710 GR MWD030 API 43.65 117.9 75.8569 3662 5879.5 7710 ROP MWD030 FT/H 1.65 4 80.31 250.488 3568 5926.5 7710 First Reading For Entire File..........5872 Last Reading For Entire File...........7710 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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.......06/11/03 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 7710.5 8350.5 RPX 7710.5 8350.5 ROP 7710.5 8401.0 RPD 7710.5 8350.5 GR 7710.5 8343.5 FET 7710.5 8350.5 RPS 7710.5 8350.5 LOG HEADER DATA DATE LOGGED: 05-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8401.0 TOP LOG INTERVAL (FT) 7710.0 BOTTOM LOG INTERVAL (FT) 8401.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.2 MAXIMUM ANGLE: 92.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 64.0 MUD PH: .0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta 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 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 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7710.5 8401 8055.75 1382 7710.5 8401 RPD MWD040 OHMM 7.01 2000 19.743 1281 7710.5 8350.5 RPM MWD040 OHMM 7.02 2000 20.3724 1281 7710.5 8350.5 RPS MWD040 OHMM 6.57 2000 20.4584 1281 7710.5 8350.5 RPX MWD040 OHMM 6.18 2000 20.2136 1281 7710.5 8350.5 FET MWD040 HOUR 0.15 13.07 0.599172 1281 7710.5 8350.5 GR MWD040 API 48.76 1 11.04 79.7318 1267 7710.5 8343.5 ROP MWD040 FT/H 0.63 790.1 246.863 1382 7710.5 8401 First Reading For Entire File..........7710.5 Last Reading For Entire File...........8401 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Library. Scientific Technical Services Comments ...............~S LIS Writing Library. Scient~c Technical Services Physical EOF Physical EOF End Of LIS File s Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 03 09:12:17 2006 Reel Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reei Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004559176 B. HENNINGSE M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING • Scientific Technical Services Scientific Technical Services 1J-102PB3 500292331772 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-NOV-06 MWD RUN 3 MWD RUN 5 MW0004559176 MW0004559176 B. HENNINGSE 0. OBI M. THORNTON M. THORNTON 35 11N l0E 2245 2446 121.30 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2642.0 7.625 5920.0 ~0~~~~~ ~ i~~o~~5 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-102 PB1 WELLBORE AT 7600'MD/3737'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 3,5 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5 REPRESENT WELL 1J-102 PB3 WITH API#: 50-029-23317-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9846'MD/3749'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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 GR 2606.0 FET 2630.0 RPD 2630.0 RPS 2630.0 RPM 2630.0 all bit runs merged. STOP DEPTH 9788.5 9795.5 9795.5 9795.5 9795.5 RPX 2630. 9795.5 ROP 2652.5 9846.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2606.0 5926.0 MWD 3 5926.0 7600.0 MWD 5 7600.5 9846.0 REMARKS: MERGED MAIN 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 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 9846 6226 14481 2606 9846 RPD MWD OHMM 0.47 2000 24.2635 14332 2630 9795.5 RPM MWD OHMM 1.54 2000 16.2108 14332 2630 9795.5 RPS MWD OHMM 2.05 2000 13.5053 14332 2630 9795.5 RPX MWD OHMM 2.11 125.86 12.1107 14332 2630 9795.5 FET MWD HOUR 0.14 83.37 1.72256 14332 2630 9795.5 GR MWD API 20.76 126.62 71.9664 14366 2606 9788.5 ROP MWD FT/H 1.65 1098.43 200.127 14388 2652.5 9846 First Reading For Entire File..........2606 Last Reading For Entire File...........9846 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER • FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2606.0 5879.0 FET 2630.0 5871.5 RPX 2630.0 5871.5 RPS 2630.0 5871.5 RPM 2630.0 5871.5 RPD 2630.0 5871.5 ROP 2652.5 5926.0 LOG HEADER DATA DATE LOGGED: 31-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5926.0 TOP LOG INTERVAL (FT) 2652.0 BOTTOM LOG INTERVAL (FT) 5926.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.9 MAXIMUM ANGLE: 82.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 96540 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: 9.875 2642.0 Fresh Water Gel 9.10 58.0 9.1 450 4.4 1.500 84.0 1.140 113.0 1.650 84.0 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 Depth Units ....................... Datum Specification Block sub-type...0 1.800 ~0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 5926 4266 6641 2606 5926 RPD MWD020 OHMM 1.26 2000 20.6338 6484 2630 5871.5 RPM MWD020 OHMM 1.54 1743.45 14.2604 6484 2630 5871.5 RPS MWD020 OHMM 2.05 129.28 11.5957 6484 2630 5871.5 RPX MWD020 OHMM 2.11 62.61 9.96614 6484 2630 5871.5 FET MWD020 HOUR 0.14 81.01 1.20528 6484 2630 5871.5 GR MWD020 API 20.76 126.62 68.3394 6547 2606 5879 ROP MWD020 FT/H 2.98 1098.43 202.148 6548 2652.5 5926 First Reading For Entire File..........2606 Last Reading For Entire File...........5926 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5872.0 7600.0 RPS 5872.0 7600.0 RPX 5872.0 7600.0 RPM 5872.0 7600.0 RPD 5872.0 7600.0 GR 5879.5 7600.0 ROP 5926.5 7600.0 LOG HEADER DATA DATE LOGGED: 05-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7600.0 TOP LOG INTERVAL (FT) 5926.0 BOTTOM LOG INTERVAL (FT) 7600.0 BIT ROTATING SPEED (RPM): HOLE INCLINATTON (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 65.0 MUD PH: .0 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 114.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 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 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5872 7600 6736 3457 5872 7600 RPD MWD030 OHMM 0.47 2000 46.7379 3457 5872 7600 RPM MWD030 OHMM 2.86 2000 24.3659 3457 5872 7600 RPS MWD030 OHMM 5.51 2000 18.0961 3457 5872 7600 RPX MWD030 OHMM 5.35 1 25.86 15.9707 3457 5872 7600 FET MWD030 HOUR 0.14 83.37 3.1851 3457 5872 7600 GR MWD030 API 43.65 117.9 76.1091 3442 5879.5 7600 ROP MWD030 FT/H 1.65 4 16.42 246.205 3348 5926.5 7600 First Reading For Entire File..........5872 Last Reading For Entire File...........7600 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 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.......06/11/03 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 RPM 7600.5 9795.5 RPX 7600.5 9795.5 ROP 7600.5 9846.0 RPD 7600.5 9795.5 GR 7600.5 9788.5 FET 7600.5 9795.5 RPS 7600.5 9795.5 LOG HEADER DATA DATE LOGGED: 08-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9846.0 TOP LOG INTERVAL (FT) 7600.0 BOTTOM LOG INTERVAL (FT) 9846.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 92.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 87225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT) 5920.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 64.0 MUD PH: .0 MUD CHLORIDES (PPM): 19500 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 124.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 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 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7600.5 9846 8723.25 4492 7600.5 9846 RPD MWD050 OHMM 4.54 27.89 11.9295 4391 7600.5 9795.5 RPM MWD050 OHMM 4.82 36.76 12.6705 4391 7600.5 9795.5 RPS MWD050 OHMM 4.65 37.92 12.7108 4391 7600.5 9795.5 RPX MWD050 OHMM 4.19 37.24 12.2386 4391 7600.5 9795.5 FET MWD050 HOUR 0.22 59.65 1.33496 4391 7600.5 9795.5 GR MWD050 API 44.02 113.49 74.134 4377 7600.5 9788.5 ROP MWD050 FT/H 6.16 581.67 162.836 4492 7600.5 9846 First Reading For Entire File..........7600.5 Last Reading For Entire File...........9846 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name .............. .UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments ................~5 LIS Writing Library Physical EOF Physical EOF Scient~c Technical Services End Of LIS File