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Home My WebLink About206-062C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-17_16032_KRU_1J-170_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16032 KRU 1J-170 50-029-23310-00 Injection Profile 17-May-25 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 206-062 T40439 5/22/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.22 08:04:05 -08'00' New Plugback Esets 6/25/2024 Well Name API Number PTD Number ESet Number Date 1J-127 PB1 50-029-23306-70-00 206-047 T39006 8-22-2006 1J-127 PB2 50-029-23306-71-00 206-047 T39007 8-22-2006 1J-170 PB1 50-029-23310-70-00 206-062 T39008 8-22-2006 1J-170 PB2 50-029-23310-71-00 206-062 T39009 8-22-2006 2K-28AL1 PB1 50-103-20385-71-00 211-134 T39010 10-13-2011 2K-28AL1 PB2 50-103-20385-72-00 211-134 T39011 10-13-2011 PBU 13-27B PB1 50-029-20947-70-00 211-048 T39012 8-11-2011 PBU 13-27B PB2 50-029-20949-71-00 211-048 T39013 8-11-2011 15-02B PB1 50-029-20697-71-00 206-072 T39014 3-7-2008 15-02B PB2 50-029-20697-72-00 206-072 T39015 3-7-2008 CD2-07 PB1 50-103-20472-70-00 203-187 T39016 2-22-2006 CD2-07 PB2 50-103-20472-71-00 203-187 T39017 2-22-2006 E-23C PB1 50-029-21763-71-00 211-053 T39018 9-30-2011 E-23C PB2 50-029-21763-72-00 211-053 T39019 9-30-2011 NS-25 PB1 50-029-23181-70-00 203-166 T39020 3-22-2004 NS-25 PB2 50-029-23181-71-00 203-166 T39021 3-22-2004 OP18-08 PB1 50-029-23449-70-00 211-059 T39022 10-14-2011 OP18-08 PB2 50-029-23449-71-00 211-059 T39023 10-14-2011 1J-170 PB1 50-029-23310-70-00 206-062 T39008 8-22-2006 1J-170 PB2 50-029-23310-71-00 206-062 T39009 8-22-2006 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-170 50-029-23310-00 206062_1J-170_Temp-Pres_11Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' 1 Regg, James B (OGC) From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Friday, July 14, 2023 8:39 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 Subject:RE: Defeated LPP/SSV on CPAI Well 1J-170 on 7.9.23 Good Morning Jim, The low‐pressure pilot (LPP) on well 1J‐170 (PTD# 206‐062, 206‐063, 206‐064) was returned to service and removed from the “Facility Defeated Safety Device Log” on 07/12/2023 as the well was shut in before we began our conformance treatment on the well. The LPP had been defeated on 06/10/2022 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 Optimization Engr <n2046@conocophillips.com> Sent: Monday, July 10, 2023 5:14 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‐170 on 7.9.23 Good aŌernoon Jim, The low‐pressure pilot (LPP) on well 1J‐170 (PTD# 206‐062, 206‐063, 206‐064) was defeated last night, 7.9.23, at 9:00 pm when the wellhead injecƟon pressure dropped below LPP setpoint as a result of communicaƟon with an offset producer (1J‐166). We brought this well online yesterday in preparaƟon for an RPPG treatment planned for tomorrow to correct the MBE between 1J‐170 and 1J‐166. The well is currently injecƟng just under our recommended rate at 1425 BWPD and wellhead pressure is at 180psi. 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-170PTD 2060620 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, Emily Zanto on behalf of Will Parker, Production Engineer GKA Optimization Engineer ConocoPhillips Alaska, Inc. Office: 907‐659‐7411 Mobile: 907‐632‐5889 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. You don't often get email from n2046@conocophillips.com. Learn why this is important From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI Well 1J-170 on 7.9.23 Date:Monday, July 10, 2023 8:57:09 AM KRU 1J-170 (PTD 2060620) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Optimization Engr <n2046@conocophillips.com> Sent: Monday, July 10, 2023 5:14 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>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-170 on 7.9.23 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated last night, 7.9.23, at 9:00 pm when the wellhead injection pressure dropped below LPP setpoint as a result of communication with an offset producer (1J-166). We brought this well online yesterday in preparation for an RPPG treatment planned for tomorrow to correct the MBE between 1J-170 and 1J-166. The well is currently injecting just under our recommended rate at 1425 BWPD and wellhead pressure is at 180psi. 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, Emily Zanto on behalf of Will Parker, Production Engineer GKA Optimization Engineer ConocoPhillips Alaska, Inc. Office: 907-659-7411 Mobile: 907-632-5889 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-05-14_21137_KRU_1J-170_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21137 KRU 1J-170 50-029-23310-00 Injection Profile 14-May-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: 206-062 T37647 Kayla Junke Digitally signed by Kayla Junke Date: 2023.05.18 09:20:15 -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-170 on 11/28/2022 Date:Tuesday, November 29, 2022 8:47:10 AM Attachments:image001.png KRU 1J-170 (PTD 2060620) 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, November 29, 2022 6:54 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-170 on 11/28/2022 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the “Facility Defeated Safety Device Log” on 11/28/2022, as the well was shut in post-diagnostics work. The LPP had been defeated on 11/09/2022 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 Sent: Wednesday, November 9, 2022 2:44 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>; Abbas, Sayeed <Sayeed.Abbas@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-170 on 11.9.22 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 11.9.2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online for the next two weeks as we conduct interference diagnostics on the nearby producer (1J-166) that we have since identified since our last round of diagnostics as the likely well in communication with this injector. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 70psi. 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 From: NSK West Sak Prod Engr Sent: Sunday, October 16, 2022 1:55 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>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com> Subject: LPP/SSV Returned to Service on Well 1J-170 on 10/16/2022 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the “Facility Defeated Safety Device Log” on 10/16/2022, as the well was shut in post-diagnostics work. The LPP had been defeated on 10/14/2022 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: Friday, October 14, 2022 12:03 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>; Abbas, Sayeed <Sayeed.Abbas@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-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. 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 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: Defeated LPP/SSV on CPAI Well 1J-170 on 11.9.22 Date:Thursday, November 10, 2022 4:29:57 PM Attachments:image002.png image003.png KRU 1J-170 (PTD 2060620) 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: Wednesday, November 9, 2022 2:44 PM 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: Defeated LPP/SSV on CPAI Well 1J-170 on 11.9.22 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 11.9.2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online for the next two weeks as we conduct interference diagnostics on the nearby producer (1J-166) that we have since identified since our last round of diagnostics as the likely well in communication with this injector. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 70psi. 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 From: NSK West Sak Prod Engr Sent: Sunday, October 16, 2022 1:55 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>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com> Subject: LPP/SSV Returned to Service on Well 1J-170 on 10/16/2022 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the “Facility Defeated Safety Device Log” on 10/16/2022, as the well was shut in post-diagnostics work. The LPP had been defeated on 10/14/2022 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: Friday, October 14, 2022 12:03 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>; Abbas, Sayeed <Sayeed.Abbas@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-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. 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 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-170 on 10/16/2022 Date:Monday, October 17, 2022 10:00:56 AM 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: Sunday, October 16, 2022 1:55 PM 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> Subject: LPP/SSV Returned to Service on Well 1J-170 on 10/16/2022 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the “Facility Defeated Safety Device Log” on 10/16/2022, as the well was shut in post-diagnostics work. The LPP had been defeated on 10/14/2022 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: Friday, October 14, 2022 12:03 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>; Abbas, Sayeed <Sayeed.Abbas@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-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. 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, December 19, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-170 KUPARUK RIV U WSAK 1J-170 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/19/2022 1J-170 50-029-23310-00-00 206-062-0 W SPT 3392 2060620 1500 0 0 0 0 150 209 209 209 4YRTST P Bob Noble 10/16/2022 30 MinPretest Initial 15 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-170 Inspection Date: Tubing OA Packer Depth 900 1810 1720 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN221016135333 BBL Pumped:1.4 BBL Returned:1.4 Monday, December 19, 2022 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Date:Friday, October 14, 2022 1:31:11 PM Attachments:image002.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: Friday, October 14, 2022 12:03 PM 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: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. 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 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:Well Integrity Specialist CPF2 To:Regg, James B (OGC);Wallace, Chris D (OGC);Brooks, Phoebe L (OGC);DOA AOGCC Prudhoe Bay Subject:CPAI 10-426 forms for shut-in MIT-IAs Date:Tuesday, May 3, 2022 2:40:42 PM Attachments:image001.png MIT KRU 2H-014A SI TEST 05-02-22.xlsx MIT KRU 1J-170 SI TEST 05-01-22.xlsx All- Attached are the 10-426 forms for the MIT-IAs that were non-witnessed due to the wells being shut in. Please let me know if you have any questions or concerns. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 .58- 37' Submit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2060620 Type Inj N Tubing 1090 1090 1090 1090 Type Test P Packer TVD 3391 BBL Pump 2.0 IA 72 1800 1745 1735 Interval 4 Test psi 1500 BBL Return 1.6 OA 135 174 172 172 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1J Pad N/A Arend / Caudle 05/01/22 Notes: Notes: 1J-170 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al In t eg r ity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0501_MIT_KRU_1J-170 9 9 9 9 9 $2*&&ZLWQHVVZDLYHGMEU -5HJJ <ECt 11'-1-70 Pn"� 'Z6606 Z-0 Re , James B (CED) From: NSK West Sak Prod Engr <n1638@conocophiIlips.com> Sent: Friday, May 14, 2021 4:51 PM I 1 To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska) Subject: LPP/SSV Returned to Service on CPAI Well 1J-170 on 5/13/2021 Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 06-063, 206-064) was returned to service and removed from the "Facility Defeated Safety Device Log" on 5/13/2021, after the wellwork had been completed and the well was shut back in. The LPP had been defeated on 6/27/2019 after the well was returned to injection post 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. Thank you, Toon Toon Changklungdee / Kelly Lyons CPF1 / WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 lac tJ�-r-7� f'-I'N zd6owzo Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �n(3I la, Sent: Wednesday, May 12, 2021 5:19 PM To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska) Subject: Defeated LPP/SSV on CPAI well 1J-170 on 5/12/2021 Jim, M The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 5/12/2021, when brought online ahead of the wellwork. The well is currently injecting at a rate of 1000 BWPD and wellhe. d ssure is on a vacuum. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeate3Safety Device Log." The AOGCC will be notified when 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. Thank you, Toon Toon Changklungdee / Kelly Lyons CPF1 / WestSak Production Engineer office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1J-170 50-029-23310-00 906951584 West Sak Injection Profile Field & Processed 30-Jan-21 0 1 2 1J-176 50-029-23364-00 906948912 West Sak Injection Profile with TMD3D Field & Processed 29-Jan-21 0 1 3 1J-180 50-029-23329-00 906811709 West Sak Injection Profile with TMD3D Field & Processed 27-Jan-21 0 1 4 1Y-19 50-029-22391-00 906880907 Kuparuk River Packer Setting Record Field- Final 3-Jan-21 0 1 5 2H-09 50-103-20050-00 906910408 Kuparuk River Multi Finger Caliper Field & Processed 8-Jan-21 0 1 6 2H-09 50-103-20050-00 906960677 Kuparuk River Packer Setting Record Field- Final 3-Feb-21 0 1 7 2N-333 50-103-20525-00 906882125 Kuparuk River Multi Finger Caliper Field & Processed 21-Dec-20 0 1 8 3A-08 50-029-21445-00 906879883 Kuparuk River Leak Detect Log Field- Final 20-Dec-20 0 1 9 3B-06 50-029-21336-00 906905927 Kuparuk River Leak Detect Log Field- Final 5-Jan-21 0 1 10 PLEASE 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 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2060620 E-Set: 34727 KU i�--(Z0 Regg, James B (CED) f n� zo(,&(�Zo From: NSK West Sak Prod Engr <n1638@conocophillips.com> 11 Sent: Monday, December 16, 2019 6:35 PM To: Regg, James B (CED) Cc: Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Mowrey, Andrew F; Autry, Sydney Subject: Defeated LPP/SSV on CPAI well 1J-170 on 12/16/2019 Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 12/16/2019, after wellwork was completed to open up injection to a low pressure zone. The well is currently injecting at a rate of 656 BWPD and wellhead pressure is on a vacuum. 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 4068.001." 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 lit I G1-1 70 P7 -t z9606zcs Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophilli�ps.com> Sent: Saturday, September 28, 2019 6:25 PM ' �,/ !'tel Lq To: Regg, James B (CED) 11��FF ( 1 11 Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1&2 Ops Supt; Mowrey, Andrew F; CPF1 Ops Supv Subject: LPP/SSV Returned to Service on CPAI Well 11-170 Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the "Facility Defeated Safety Device Log" on 9/24/2019, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 840 BWPD at 300 psi wellhead pressure. The LPP had been defeated on 6/27/2019 after the well was returned to injection post 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. Thank you, Toon Toon Changklungdee / Danila Shutemov WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 o(,( I J__ ho pit Z0606zL Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, June 27, 2019 4:42 PM �'Pt, 7/x/1 To: Regg, James B (CED) j Cc: Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Mowrey, Andrew F; Autry, Sydney Subject: Defeated LPP/SSV on CPAI well 1J-170 on 6/27/2019 Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 6/27/2019, after the well was returned to injection after an extended shut-in period. The well is currently inle t nicgat a wellhead pressure of 10 psi and a rate of 265 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 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 6S9-7234 Pager: (907) 659-7000 pp 497 • • 011( to- c Regg, James B (DOA) Prb ZO za From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, May 12, 2018 5:23 AM 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-170 Jim, The low pressure pilot (LPP) on well 1J-170(PTD#2064 206-063, 206-064)was returned to service and removed from the "Facility Defeated Safety Device Log" last nig t, 5/11/2018, after the well was shut-in for diagnostic wellwork. The LPP had been defeated on 5/6/2018 after wellhead pressure fell below the LPP setpoint of 500 psi while injecting at recommended rate.This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED JUN 0120k8 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, May 10, 2018 8:42 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 1J-170 (PTD 206-062) Report of suspect IA communication Attachments: 1J-170.pdf; 1J-170 90 day TIO trend 5-10-18.JPG Chris, KRU West Sak injector 1J-170(PTD 206-062)was found yesterday to have an IA fluid level of 5926' indicating some ty e of communication may be present. The plan is for the well to be shut in and freeze protected after which the IA will b loaded with fluid and an MITIA will be performed. If the MITIA passes the well will be BOI for a 30 day monitor period. If the MITIA fails further diagnostics will follow. Follow up email correspondence will be made subsequent th monitor period or through sundry if a corrective action is necessary. Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WEA 1 • • Ku rS-(7o Regg, James B (DOA) From: Braun, Michael (Alaska) <Michael.Braun@conocophillips.com> Sent: Tuesday, May 8, 2018 9:42 AMS I To: NSK West Sak Prod Engr; Regg,James B (DOA) 16 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv PF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Fox, Pete B; Sudan, Had Hara; NSK Optimization Engr Subject: CORRECTION: LPP/SSV Defeated on CPAI Well 1J-170 My apologies for the incorrect title in the previous email. The pilot was defeated, not returned to service as the title suggested. Get Outlook for iOS From: NSK West Sak Prod Engr<n1638@conocophillips.com> Sent: Tuesday, May 8, 2018 8:28 AM Subject: LPP/SSV CPAI Well 1J-170 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> Jim, SCANNED 1 A Please note that the low pressure pilot (LLP/SSV)was defeated yesterday on welllJ-170(PTD#206-062,206-063,206- 064), a WestSak seawater injector. The well is taking at our recommended injection rate of 750bwpd at less than 500 psi WHP.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 ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 1 Regg, James B (DOA) r From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday,January 6, 2018 2:08 PM , q I(6( (s 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;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI Well 1J-170 - 1/6/2018 Jim, The low pressure pilot (LPP) on well 1J-170(PTD#206-062,206-063,206-064)was returned to service and removed from the "Facility Defeated Safety Device Log" today, 1/6/2018, after the well was shut-in. The LPP had been defeated on 1/4/2018 when the well was returned to service after an extended shut-in period for wellwork.This notification is in accordance with "Administrative Approval No. CO 4068.001." 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 • • int )6-- iso Regg, James B (DOA) a0oe From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday,January 5, 2018 6:44 AM 1 1 5I(C7 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-170 on 1/4/2018 Jim, The low pressure pilot (LPP) on well 1J-170(PTD#206-062,206-063,206-064)was defeated yesterday, 1/4/2018, after the well was returned to service to perform wellwork after an extended shut-in period.The well is currently injectingat a wellhead pressure of 428 psi and a rate of 807 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 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 SCANNED n Pager: (907) 659-7000 #497 1 c4ifl m N1/49 tvo C: O�m U r J t ‘.- --- QY voL = 3 a - 4 > �, .�,,. Y 03 O 'B ro C u N 0 > O 'C N ra O LO L, a` a a) c aJC T ,F- ro 0 a ¢ Yi ❑ U � a 6 m � r r r r r r r r r n n L aJ Ou L J l7 �, >, >, T T T >, E a•+ L -p O to a O a fO f6 10 (0 r0 la r0 CC CC CC CC L -6 . 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ILI i 'L atiN � � N(I) U) ) U) U) U) CO C u )s' o CO CO CO CO 0 0 0 0 0 0 0 c W K `,;n ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ C VI co U IA1 S \ _ 0 0 0 0 0 0 0 0 0 0 0 9 c 0 0 0 0 0 0 0 0 0 0 0 o p0 V M .- N N O N N N C)) v) U) CO L 0 4t C) N N 0 c") r 0 0 C) C) 0 )' Ou 0 CO r CO r r 0 N N r O IN�+ d N N N N N N N N N N N N L Q ' a C) C) C) C) C) C) C) M C) C) C) C) U w p �y N N N N N N N O N N N N '[ O1 O 0 O O O 0 0 O O 0 0 - ' O O O O O O O O O O O O 04 U) U) U) U) N U) U) U) U) U) U) U) 0. 0 Fes.' rp _._..;U., C! _CC v L. a W «+ Y w cc L. O u ar ¢ I� 1)9 'Q CU Cil .-i Q o N M O o 0o m o o rn +° a E z I, Z O r 0 0 0 N N O = oc ,n E L a d ¢ W N N N M N r r N N Z w ra VI VI = r 4 t ^ w C 4-+ f0 v) C3 p u 0 O C/� $ Q F= aL a Q (9 cc • • zc0 Co' WELL LOG TRANSMITTAL#902914075 To: Alaska Oil and Gas Conservation Comm. January 15, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DA7A LOGG D Anchorage, Alaska 99501RECEIVED 2-i 520, K.BENDER AN 2 0 c�.. RE: Injection Profile : 1J-170 AOGCC Run Date: 11/14/2015 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 1,J-170 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23310-00 Injection Profile Log 1 Color Log 50-029-23310-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating �� 1 � ti Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: D ✓Q� a�h.�t,� 6,,ixeet Zoca-vg 2_ 242- 1 WELL LOG TRANSMITTAL RECEIV NOV 032015 PROACTivE DIAgNOSTIC SERVICES, INC. DATA LOGGED AOGCC tt/.(/2015 ;.i.K.BENDER To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952cm40E0 1) Injection Profile 31-Oct-15 1J-170 BL/CD 50-029-23310-00 2) Signed : //) ,AL2.42/u Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx 2-ac- oc,~Z. • • 2-0O2-6c) WELL LOG TRANSMITTAL DATA LOGGED 9/22/2015 K.BENDER To: Alaska Oil and Gas Conservation Comm. August 31, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RC Anchorage, Alaska 99501 2 2 RE: IPROF Log with TMD3D: 1J-170 Run Date: 8/8/2015 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-170 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-23310-00 IPROF Log with TMD3D (Field print) 1 Color Log 50-029-23310-00 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. Anchorage, Alaska 99518 SCANNED Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 122A.124t4ze 15.40.eeet • Regg, James B (DOA) From: Patterson, Amanda [Amanda.Patterson @conocophillips.com] Sent: Thursday, June 06, 2013 3:09 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Targac, Gary; Seitz, Brian; CPF1&2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; NSK Prod Engr Specialist; CPF1 Prod Engr Subject: Correction: LPP/SSV returned to service 1J-170 5/28/13 Jim: I incorrectly stated that a downhole choke had been installed. Please disregard. Thanks, Amanda Patterson �N�D FEB 2 0 201 West Sak Production Engineer sc� ConocoPhillips Alaska,Inc. Office:(907)265-6782 Cell:(281)796-5044 ;on,Amanda y,June 06,2013 2:54 PM aalaska.gov' Lead Techs;CPF1 Ops Supv; NSK Problem Well Supv;Targac,Gary;Seitz,Brian;CPF1&2 Ops Supt;Jensen,Marc D; Hutcherson,Mark R; Patterson,Amanda; NSK Prod Engr Specialist;CPF1 Prod Engr PP/SSV returned to service 1J-170 5/28/13 Jim: The low pressure pilot(LPP) on West Sak injector 1J-170 (PTD 206-062/206-063 L1 /206-064 L2)was returned to normal service on May 28, 2013, when the wellhead injection pressure increased to a level above 500 psi. A-downsle - • _ - -_ _• - - ! _. This pilot had been defeated on March 3, 2013; and notification was sent in accordance with "Administrative Approval No. CO 406B.001." As of 15:00 hours on June 6, 2013, the wellhead pressure is 554 psi at an injection rate of 1130 BWPD. Please let me know if you have any questions. Regards, Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska,Inc. Office:(907)265-6782 Cell:(281)796-5044 1 1 • ftt I3-170 Zi z_o Regg, James B (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Sunday, March 10, 2013 2:54 PM 1 _ 31/11t3 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Targac, Gary; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; Patterson, Amanda; NSK Prod Engr Specialist; CPF1 Prod Engr Subject: LPP /SSV defeated on 1J -170 on 03/10/2013 Jim, The low pressure pilot (LPP) on 17 -170 (PTD 206 -062 / 206 -063 L1 / 206 -064 L2) was defeated on 3/10/2013 when the well was returned to service after being shut in for wellwork. Current wellhead pressure is 425 psi and the injection rate is 250 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. thanks, SCANNED JUL. 2 2 2013 Dana Glessner /David Lagerlef ConocoPhillips Alaska, Inc Kuparuk CPF1 Production Engineer office (907) 659 -7493 Dana .Glessnerconocophillips.com 2_0c,, -06. 2, 353 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 3, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED JUL 2 $ n13, RE: Bottom Hole Pressure Survey : 1J -170 Run Date: 12/2/2011 The technical data listed below is being submitted herewith. Please_address any prQbl s_a ; - concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -170 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23310 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23310 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com y vi Date: 4(9(0— / 'woe / David P. Jamieson Supervisor, Reservoir Engineering , Greater Kuparuk Area Developrrmt T e A ConocoPhi Alaska, Inc. C4 oPhillips n a e Anchorage, , AK M01 phone 907.385.13343 September 23, 2010 SEP 2 3 2010 Daniel T Seamount, Jr., Commission Chair Alaska Oil and Gas Conservation Commission • 333 W. 7th Ave #100 ll Anchorage, Alaska, 99501 -3539 RE: West Sak Viscosity Reducing Water Alternating Gas Pilot Project Administrative Approval Area injection Order 213.044 Administrative Approval Conservation Order 4066.009 Dear Mr. Seamount: Enclosed is the West Sak Viscosity Reducing Water Alternating Gas (VRWAG) Pilot Project Status Report for the reporting period of July 1 2009 through June 3&, 2014. As per conditions described in the pilot approval document, this report was to be submitted to the Commission by September 30, 2010 and contain items specific to the project performance and achievements. Please contact R.Scott Redman (263 - 4514), Mark Hutcherson (265 - 1034), or Lubbie Jenkins (265 -6912) if you have questions or require additional Information. Sincerely, 7 W F/V Sill- David Jamle.in Supervisor, Reservoir Engineering "— Greater Kuparuk Area Development cc: King, Warwick. Jenkins, Lubber Seitz, Brian Rodgers, James I �0 -o( � r ConocoPh WS -VRWAG PILOT P STATUS REPORT REPORTING PERIOD 7/l/2009 — 6/30/2010 Submitted: 9/30/2010 Prepared By: 1449 Mark Hutcherson, West Sok Drillske Petroleum Engineer Reviewed B � Y R , West Sek Reservoir EngMeer Approved By: W&v'rlt David Jax�, GKA Reservoir E Supervisor I I WS -VRWAG Pilot Protect Status Report Executive Summary This document is the annual West Sak Viscosity Reducing Water Alternating Gas (VRWAG) Pilot Project Status Report, submitted to the Alaska Oil and Gas Conservation Commission (AOGCC), as required by Area Injection Order 28.044 and Conservation Order 4066.009. The AOGCC, through a letter dated September 9, 2009, requires that the operator provide the Commission with a report on the status of the VRWAG pilot project by September 30 of each year, beginning in 2010. The WS -VRWAG Pilot Project entails injecting hydrocarbon enriched gas for 6 WAG (Water Alternating Gas) cycles in 4 patterns in the West Sak Field 1 E Drillsite and 1 J Drillste. An incremental recovery of 3 -6% of the original oil in place is expected in addition to the -20% waterflood recovery estimate. Four injectors were selected for the pilot (1E -102, 1E -117, 1.1-122, and 1J -170) targeting five offset producers on gas lift (1 E -121, 1 E -170, 1 J -168, U-166, and U-120). To date. none of the 4 targeted patterns is mature enough in the FOR poject to show enhanced production. However, t he 1E -102 injector experienced an MBE (Matrix Bypass Event) with the 1 E -121 producer 37 days into the first MI cycle. it is believed that the MBE is unrelated to the pilot project and would have occurred regardless. The other 3 patterns do not show any adverse effects from to the M1 and are conti nuing forward as planned. ooN -23 I i ao5 - �G I E - iii ao� -oho IO' -ia2 006 - oGa i s — dq& Introduction The WS -VRWAG Pilot Project is an expansion of the current development plan for the West Sak Reservoir with potential to significantly increase the recovery of oil from the pool. The pilot was approved by the AOGCC on 9/10/09 and the first VR -WAG cycle began 11/23/09 on two of the four patterns, which effectively started the clock on the 36 month planned pilot. The graphic below shows and field overview with the patterns outlined in red: 1 1 E -1 2 •may , _ •''ate --.•_ jest ` A F I•'Ti tw� 1 t V i 1 �ip� „•f r k4� to 1J 122 ` lad 1E -11 f LO? 48 _. i r5 - 6 . �J -1 I Are rr S y N f � .•F 1 1 1 •s d_._ --- - fz 57$ ___ � �. of 4t yy i t7 }b 1 3 18 Proiect Performance and Achievements It is still early in the VR -WAG Pilot to detect any uplift or response from the producers, 1 E -102 Pattern . Offset producers: 1 E -121 & 1 B -101 (possible) o . Dual lateral well selected for D lateral injection only (B lateral was previously isolated due to pre -pilot MBE) cl �ej . Began first MI cycle 11/23/09 • Experienced MBE in D lateral on 12/29/09, 37 days t after beginning MI, and was shut -in Pulled from pilot and remains SI to this date awaiting o MBE remediation Due to the MBE occurring in 1 E -102, replacement candidates are being reviewed. ' No premature breakthrough events detected No oil production response from FOR detected at offset producers LL 1 1E -117 Pattern w y • Offset producers: 1E-170, U-168 & 1 E -166 (Possible) + • Tri- Lateral Injection Well (A, B, and D Sands)w ,- • Began first MI cycle 11/23/09 / • Completed first MI cycle 3/15/10 and was on produced water injection through the end reporting period of 6/30/10 / • No premature breakthrough events detected • No oil production response from FOR detected at offset producers W I J -170 Pattern / • Offset producers: 1J -166 & iJ -168 (Possible) • Tri- Lateral injecting to A & D Sands only (B Sand isolated from pre -pilot MBE to 1J -166) i Began first MI cycle on 4/4/10 • On first MI cycle through the end of reporting period of 6/30/10 with plans to place back on water injection in July 2010 • No premature breakthrough events detected f No oil production response from FOR detected at f offset producers o �f E i- � 1` ti 1J -122 Pattern Offset producer: 1J -120 • Tri - Lateral injecting to A, B & D Sands r ° • Began first MI cycle on 4/4/10 • On first MI cycle through the end of reporting period of , 6/30/10 with plans to place back on water injection in July 2010 • No premature breakthrough from detected • No oil producition response from FOR detected at offset ' producers i ,� Injection Performance and FOR Response The VRWAG flood is being managed by injection pressure. Operating rates vary according to geology, well configuration, pore pressure, and injection pressure. Injection rates have been limited to 2.0 MMSCF /d until the maximum operating injection pressure is achieved. At that time, injection rate is controlled by the downhole injection pressure limit. When the wells are converted back to produced water injection (PWI), the downhole pressure remains as the injection rate control limit. The following graphs indicate water /gas injection rates on the 4 pilot injectors and oil production rates and GOR on the 4 primary focus producers and 2 possible response producers. 1E -102 Water /Gas Injection Daily Rates ® �.oLO wai ❑ ruio cni 2100 1500 1400 1360 1300 1°20 1200 1680 110° 1540 1000 1100 Q SW s G em ?C0 se° a � 600 840 500 700 106 560 300 420 200 280 100 140 o ° tan 09 F4b08 11x06 Ap08 Nsy CS J-M R03 "08 Sep09 Od03 N -09 0a 02 Jan10 Fa610 Mr10 A9110 May10 An 10 1E -117 Water /Gas Injection Daily Rates 1700 ®><�� •vFi ®<ni� ew.� 67 ❑ • _ ❑ . _ ❑ e uw� 2406 1600 1888 1500 1770 1400 1652 1300 1571 1200 1416 i 1100 1298 n p low 1180 0 t; 300 1062 � 700 � 62c 600 500 400 ' 472 700 354 j 276 160 / 116 0 0 Jan03 Fe603 MsM Ap 05 M 709 J-15 JJ03 AW09 S.03 0dQ9 N -00 IN 09 Jan 10 ie810 Ms /0 WO M+Y10 J-10 1J -170 Water /Gas Infection Daily Rates 1800 p veo_n M, C3 u -no evwi E3 u- nu_ovwr [3 U -00_A GIFI O u- uo_cczar 2484 1700 2346 1600 2208 1500 2070 1400 1932 1300 'i 1794 i 1200 '�. < 1656 > „00 1518 o r4 1000 13805 a 900 1242 $ z 800 ` �jJ``�� 1104 700 1 tJ sm K f U, 828 600 690 400 fr M2 z1. 300 414 200 276 100 % 138 0 0 Jen O9 Feb09 Ma09 Apr09 May O9 Jun09 A109 Aug09 Sep09 Oc109 Nov09 Dec09 Jan10 Feb10 Mar10 Apr10 May10 Jun10 1J -122 Water /Gas Infection Daily Rates 1100 p uuZe vwr 0 uu^ZO Vai O unLscwr p vrzz.ocwi 2926 low 2660 900 2394 800 2126 i 700 1662 i 600 '� 1596 z 'g 500 .1330 � L a { 400 1064 300 798 200 532 100 � 0 0 Jan 09 Feb09 Mar09 Ap09 May09 J-09 JU09 Aup09 Sep O9 Od09 Nov09 Dec09 Jan10 Fab10 Mr10 Apr/0 My10 JLn10 A'. 1E -170 Oil Production Daily Rates 1300 _ _ _ ® IE -170_A OPRI _ ❑ IE -170_8 OPRI ❑ IF-170 0 OPRI 1200 1100 1000 900 > 000 700 $ 600 n` � 500 400 � 100 0 Jan 09 Feb 09 Mar 09 Aix 09 May 09 Jun 09 JU 09 Aug09 Sep O9 0009 PIOV Da09 J-10 F4b10 MrW Ap10 Mar10 Aet10 U -168 Oil Production Daily Rates 1300 r63 U-10 0 IJ -Kt S OPRI O IJ -Ke_O OPRI 1200 1100 1000 900 > B0 P 700 8 600 4 I 400 300 200 100 0 Jan09 FAN Mr09 Ap09 M4y09 Jun09 JJ09 Aug 09 SepDI Dd09 Mm OS Dec09 J4n10 Feb/0 Mr10 Ap10 M4y10 JIa10 1J -166 Oil Production Daily Rates 4000 M IJ -166 A OPRI IJ-KC B OPRI 13 IJ-KB O OPRI 3700 4 m G 8 6 O 1000 0 Jan 09 Feb 09 M.09 Ap 09 May 09 Jun 09 M09 A g 09 Sep 09 Ocl 09 Nov 09 Dec 09 Jan 10 Feb 10 Mar 10 Ap 10 May 10 Jun IO 1J -120 Oil Production Daily Rates lj420 A OPRI E3 W208 OPR7 IJ-120 OOPRI 1400 1300 1200 1100 1000 900 m ow G % 700 n` 6O0 0 500 NA 300 100 0 Jen 09 Feb 09 M.09 Ap 09 May 09 Jun 09 Jul 09 Auq 09 $4009 OU 09 Nov 09 Dae 09 Jen 10 Fa610 Ma 10 Ap 10 May 10 JIn 10 i 1B -101 Oil Production Daily Rates 1600 0 18101 B OPAI Q 18 -101 D OPRI 1500 1100 1300 1200 1100 1000 a m 900 % OW 8 700 0 600 500 100 300 200 100 0 Jan 09 Feb O9 M&09 Apr09 May O9 Ju 09 JJ 09 AuF09 Sap09 Oct C9 Nov O9 Dec O9 Jan1D Feb10 Ma/10 Ayr10 May10 Jw10 1E -121 Oil Production Daily Rates 1000 SE-121 BOPRI 0 IE- I21_DOMI 90D ow 700 a 600 m 500 0 100 300 200 100 el Jm OS F4b09 Ma 00 Apr 09 Mar 09 Jra109 J1J 09 Aug 09 Sap 09 Oct 09 Hoy O9 Dac 09 Jan 10 Fab /0 Mr 10 Apr 10 My tO JIn 10 1E -123 Oil Production Daily Rates 500 Q IE -123 OOPRI C3 ff- f22_OOPRI 400 300 v a 8 0 200 100 0 Jan 09 reb 09 Marta Apr 09 May 09 Ju109 JU 09 Aug 09 SeP OS Od D9 Nov 01 Dec 09 Jen 10 Feb 10 M&10 Apr 10 May 10 Jw 10 FOR Response Plots The FOR Response Plots are shown for the following injector /producer well pairs: I njector /Producer Open Infector Zones Open Producer Zones 1E-102/1 E -121 D Sand D and B Sands 1E-1 17/1 E -170 D, B and A2 Sands D, B and A2 Sands 1E- 117/1J -168 D, B and A2 Sands D, B and A2 Sands 1J- 170/1E -166 D and A2 Sands D, B and A2 Sands 1J- 122/lJ -120 D, B and A2 Sands D, B and A2 Sands 1E-10211 B -101 D Sand D and B Sands 1 E -102/1 E -123 D Sand D and B Sands Each set of FOR Response Plots includes an Oil Production Plot, a GOR and Watercut Plot and a VRWAG Injection Well Plot on the same page. The injection plot shows the timing of water and gas slugs on the same time scale as the offset production well's Oil Rate, GOR and watercut performance. I • i . 1 E -10211 E -121 VRWAG Response Plots West Sak 1E -121 Oil Production 3000 -- 2500 - -oil production 92000 N C y c 1500 U 9 7 O a` 1000 'o 500 _.... - _._ _.. ...._.__._ .._.. -- 0 Jan - 05 Jan Jsnfi17 Jif08 Dec-08 Dec-09 Dec -1 West Sak 1 E -121 GOR and Watercut 100 45 90 4.0 ....._ - Wate rC Ui:..... __.... ........ Bo 3.5 70 ro 30. 60 U � N 2.5 __._ _........ _. ... ..___.. 0 O 20 .. .._._. _.. - __ __ 40 3 1.5 _ ___ _ 30 1.0 20 0.5 10 0.0 0 Jan-05 Jan-05 Jan-07 Jan -08 Dec-08 Dec-09 Dec -10 West Sak 1 E -102 VRWAG Injection Well 3500 o 3000 —Gas Injection Rate rn 2500 —Water Injection Rate 0 a 2000 U. V N 1500 ai to c 1000 O_ d 500 0 Jan-05 Jan-06 Jan -07 Jan08 Dec-08 Dec-09 Dec -10 1E- 11711E -170 VRWAG Response Plots West Sak 1E -170 Oil Production 2500 - - - - -- 2000 - oil roduction 1500 N G u 0 1000 a` O 500 0 __. Jan -05 Jan-06 Jan -07 Jan-M Dec-08 Dec-09 Dec -1 West Sak 1E -170 Watercut and GOR 5.0 -- -- - - - --- - -- --- 100 4.5 -- gor 90 40 WaterCGt 3.5 _.,_. ..__._.. 70 O e 3.0 _.. _...... 60 � y 25 ._..__ 50 g u` e 2.0 _.. ....._ __ --__.. _. _._..__... 40 3 K c 1.5 30 0 1.0 - ._. -__ . _.. _ .. .: ........._.. ..._.. 20 c 0.5 .... .. __._ -. _..._. 10 0.0 0 Jan -05 Jan-p6 Jan -07 Jan-08 Dec-08 Dec-09 Dec -10 West Sak 1E -117 VRWAG Injection Well 4000 3500 Gas Injection Rate ° —Water Inj ection Rate 3000 __._......__... 0 2500 vUi 2000 b 1500 _....._... ..._... -.. y c "c 500 _._.._. __..... 0 Jan-05 Jan-06 Jan-07 Jan -08 Dec-08 Dec-09 Dec -10 1 E- 117/1,1-168 VRWAG Response Plots West Sak 1J -168 Oil Production 2500 ------- -.__... ._-- --- -- - --- -- - ----- - - - - -- 2000 1 —oil roduction A (n 1500 O O 1000 a` - I O 500 0 .._... _..._._�....�. .._ Jan-05 Jan-08 Jan -07 Jan -08 Dec-08 Dec-09 Dec -1 West Sak 1J -168 GOR and Watercut 5.0 100 4.5 90 4.0 gor 80 3.5 — Wate 70 m 3.0 60 LL �{ (n 2.5 -_.- _. 50 0 � y A o 2,0 40 3 1.5 _. .._ _ 30 1.0 .. -.. .. _.___. -..__. 20 015 -_.__ _. _ _. - _ _ 10 0.0 p Jan-05 Jan46 Jan -07 Jan-08 Dec-08 Dec-09 Dec -10 West Sak 1E -117 VRWAG Injection Well 4000 r 3500 —Gas Injection Rate A m — Water Injection Rate � 3000 T `o ^ m 25 C LL y 2000 1500 1000 u d c 5w 0 Jan-05 Jan-06 Jan -07 Jan-08 Dec-08 Dec-M Dec-10 • a 1J- 12211J -120 VRWAG Response Plots West Sak 1J -120 Oil Production 3000 -- — 2500 - -- oil roduction 0 2000 1500 . _ U v pp d 1000 _._ _..... .. ..._ 6 500 _..... _ __ _ _.... ... ... _. 0 Jar. -05 Jan-06 Jan -07 Jan-08 Dec-08 Dec-09 Dec-1 West Sak 1J -120 GOR and Watercut 5.0 t 45 ............__..._...__.... 90 4.0 9or so — Ovate rc ut 3.5 70 Le 3,0 60 T R w O 2.0 40 __..._ _ _..__ _....__._. 3 1.5 30 1.0 20 0.5 _. _._ _.. __.. 10 0.0 i 0 Jan -05 Jan -06 Jan -07 Jan-06 DwAS Dsot1B Dec -10 West Sak 1J -122 VRWAG Injection Well 4000 T 35W _...._ 9 Gas Injection Rat! N 3000 —Water Injection Rate 0 it 2500 Q N 2000- «i 1500 ..._ ...__.. .__.. 0 1000 V d 'C 500 ._. ._.... _... 0 Jan -05 JW-06 Jan -07 Jan-08 Dec-08 Dec-09 Dec -10 s • 1J- 17011E -166 VRWAG Response Plots West Sak 1J -166 Oil Production 600v - - _ -- — - -- 5000 _ oil production O 4000 0 3w,0 c V G a 2000 O 0 Ja1-05 JarW7 Jan -M Dec-06 Dec-09 Dec -t West Sak 1J -166 GOR and Watercut 5.0 100 4.5 - _..... 90 --gor 40 — WaterCUt 80 3.5 70 3.0 ......_._ ._. _... _.._ _..... 60 LL x CQ 2.5 50 d p 2.0- - 40 3 1.5 -_ __..____ 30 1.0 -- __ 20 0.5 _.. _.._...... ._ ___... __.. 10 0.0 0 Jan-05 Jan-06 Jan-07 Jan-08 Dec-06 Dec-09 Dec -10 West Sak U -170 VRWAG Injection Well 4500 -- ---. -- - 4000 _.... .. c ion Rate sew Gas Inject —Water Injection Rate p 3000 e 2500 - - U N 2000 w 1500 t ' c tttt _ O 1000 1 i L ( f 500 Jan -05 Jan -06 Jan-07 Jan-08 Dec-08 Dec-09 Dec-1C ! • 1E- 10211B -101 VRWAG Response Plots West Sak 1B -101 Oil Production 3000 _---------.._.._ ._.._- .--- -_----------- _.. -- - -- — - -- 2500 - -oil production _0 2000 N C t 1500 9 � O a 1000 O 500 0 Jan -03 Jan-04 De -04 Dec-05 Dec-0s Dec -07 Dec-08 Dec-09 Dec -10 West Sak 113-101 GOR and Watercut 20.0 -- -- 100 180 gor 90 16.0 — WaterCUt &1 pppp 140 70 y 12.0 ._......__...._.... 60 zt LL 10.0 _ _.. 50 0 8. _ 40 3 O t9 4.0 -_. .. _.. 20 2.0 10 00 0 Jan-03 Jan-04 Dec-04 Dec-05 Dec-06 Dec -07 Dec-08 Dec -09 Dec -10 West Sak 1 E -102 VRWAG Injection Well 4C00 - - -- _ -- 3500 Gas Injection Rate 0 -° Water Injection Rate 1000 `o 2500 2000 g 1500 _.. _..__. _.,..__.._._.... A G! 4 1000 'c 500 0 Jan Jan-04 Dec-04 Dec45 Dec-06 Dec -07 Dec Dec Dec - 1E- 10211E -123 VRWAG Response Plots West Sak 1E -123 Oil Production 4000 -- -- --- - - - - -- ---- -- --- 3500 oil production] 3000 A 0 I 2500. N C c 2000 U CL 1500 0 1000 500 0 Jan -03 Jan -04 Dec -04 Dec -05 Dec-06 Dec -07 Dec-08 Dec-09 Dec -10 West Sak 1 E -123 GOR and Watercut 5.0 - - -- -- 100 4.5 �-- gor 90 4 — WaterCUt - -. - -. so 3.5 ....... _._ . 70 to 30 60 0 iz U g 25- 50 2 O 2.0 40 3 1.5 _ 30 1.0 20 0.5 10 00 0 Jan-03 Jan-04 Dec-04 Dec -05 Dec-06 Dec -07 Dec-06 Dec-09 Dec -10 West Sak 1 E -102 VRWAG Injection Well 4000 3500 —Gas Injection Rate ° —Water Injection Rate 3000 o 2500 D LL y 2000 1500 o_ 1000 S 500 0 Jart03 Jan-04 Dec-04 Dec-05 Dec-06 Dec -07 Dec-08 Dec-09 Dec - Monitoring and Testinq Per the results of gas sample tests from offset producers, no significant gas breakthrough is detected and, therefore, the VR -WAG cycles will continue as planned on the three remaining VR- WAG injectors. Primary focus for MI producer response monitoring is on wells 1E -170, 1J -168, 1J -166, and 1J- 120. A plot of 1E -121 produced gas analysis is also included to show the impact of MI breakthrough from the MBE on gas composition. 1E -121 Produced Gas Samples 1E -121 Gas Analyses 1000 - 100 m 10 c d d 1 IL 0.1 0.01 CO2 N2 C1 C2 C3 I -C4 N -C4 I -05 N -05 C6 C7 C8 C1 /C3 Ratio Component p 5!4!09 ®12/29 012/31/09 o 1/15110 ■ 7/2110 1E -170 Produced Gas Samples 1 E -170 Gas Analyses 100 10 — m m c 1 d m a 01 0.01 L Ill" CO2 N2 C1 C2 C3 I-C4 N -C4 I -05 N -05 C6 C7 C8 C1 /C3 Ratio Component ❑ 10/17/09 0 12!30/09 ❑ 3/7/10 O 7/6/10 1J -168 Produced Gas Samples 1J -168 Gas Analyses 100 10 d a, c 1 _ d U U 0.1 - - - 0.01 CO2 N2 C1 C2 C3 I -C4 N -C4 I -05 N -05 C6 C7 C8 C1 /C3 Ratio Component ❑ 10/17109 a 12/30/09 ❑ 317/10 ❑ 7/6110 1J -166 Produced Gas Samples U -166 Gas Analyses 100 — 10 – - a� m f9 c 1 m U d a 01 -- 0.01 CO2 N2 C1 C2 C3 I -C4 N -C4 I -05 N -05 C6 C7 C8 C1 /C3 Ratio Component p 5/4/09 ■ 5/21/10 o 7/14110 1J -120 Produced Gas Samples 1J -120 Gas Analyses 100 — - 10 d a u m a 0.1 0.01 CO2 N2 C1 C2 C3 I -C4 N-C4 t -05 N -05 C6 C7 C8 C1 /C3 Ratio Component 0 4121/10 a 6/27/10 ❑ 7/12/10 1 E -121 and 1 E -123 will be monitored for VR -WAG Pilot- specific response, but none is expected to be observed since MI was active for such a short period of time on the 1E -102. 113-101 was determined initially to potentially receive support from the 1E-102. The 113-101 was brought online following a workover on 4/10/10. Following flush production resulting from an extended shut -in period, the well has since gone back to pre - workover rates indicating there is no significant support from the 37 day gas injection period on the 1 E -102. However, the 1 B -101 will continue to be monitored. MBE Development The 1 E -102 experienced an MBE shortly after commencing the first VRWAG Pilot gas injection period. It is possible the gas injection cycle accelerated the rate at which the MBE path became fully established, but in all likelihood, the MBE path was nearly developed at the time the VRWAG Pilot began and would have fully developed within a short period of time regardless. The three remaining patterns continue to be monitored closely to determine if the pilot program has affected the likelihood of an MBE to occur. To this date there is no evidence to suggest any change in likelihood. • MEMORANDUM TO: Jim Regg ~~,~ s ~ ~ ~ ~ ~ P.I. Supervisor ~t 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-170 KUPARUK RIV U WSAK 1]-170 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: KUPARUK RIV U WSAK 1J-170 Insp Num: mitRCN100516152417 Rel Insp Num: API Well Number: 50-029-23310-00-00 permit Number: 206-062-0 Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ]J-170 ~ Well Type Inj. G TVD 33 92 `~ IA 440 2600 ~-~~--_ _ 2560 2550 T- ___ P.T.Di 2060620 TypeTest SPT i TCSt psl 2600 I QA ~ 155 i 304 243 217 ~ 6 Interval axxTST p~F, P _ Tubing 1863 L 1865 1866 186 Notes: ~,~; n y-~(~ ~~~- / S~vPs,~ +s. z ~ ~i 't h ' 1:: S Monday, May 24, 2010 Page 1 of 1 • • ~~ `~~:: .~ 4~ . ~~.. ~~ ~- ~ ~' +~,~~ ~ '~"' _ , ~ ~ s MICROFILMED 6/30/201 ~ 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. ~ ~ ©6~ FIELD /UNIT /PAD: Kuparuk /KRU / 1J ~a .. ' ~ d DATE: 05/14/10 ' OPERATOR REP: Colee /Phillips - AES AOGCC REP: Bob Noble ~ ~ ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubing 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' Tubing 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casing 809 1,690 1,640 1,620 P/F P Notes: OA 141 214 174 156 WeII 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 3,437' Tubing 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' Tubing 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 -,,~.,-: F E~ t ~J v~ MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s r 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 05-14-10.x1s ~~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI~ AFR 2 ~ ~~~PORT OF SUNDRY WELL OPERATIONS t. Operations Pertorr~d:~' ~ (r11$310~ air w ell Plu Perforations Stimulate i Other WINJ to WAG 11~~5KK~a S' p ~ g ~ ~ ~ Conversion AIO~(>~8t~~ Pull Tubing ~ Perforate New Pbol r Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown [ Rerforate (~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 206-062 3. Address: ~. API Number: P. O. Box 1 0360, Anchorage, Alaska 99510 Stratigraphic ~ Service ~ 50-029-23310-00 7. Property Des ati 8. Well Name and Number: ADL 25660 & 25661 ~ 1J-170 9. Field/Pool(s): Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 12479 feet Plugs (measured) None true vertical '~ 3702 feet Junk (measured) None Effective Depth measured ~ 12468 feet Packer (measured) 6360 true vertical 3701 feet (true vertucal) 3392 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108 108 0 0 SURFACE 3011 10.75 3041 2146 0 0 INTERMEDIATE 7867 7.625 7894 3649 0 0 LINERA-SAND 5539 4.5 12470 3701 0 0 Perforation depth: Measured depth: Slotted & Blank Linerfr 7896-12434 y ~`~~;w~ ~ ~~~ ~, (~ ~~ ~~ ; True Vertical Depth: 3650-3700' ' '~"~" ..,,-., Tubing (size, grade, MD, and TVD) 4.5, L-80, 6382 MD, 3392 TVD Packers &SSSV (type, MD, and TVD) Packer -Seal assembly, ZXP liner top 6360 and 3392 TVD SSSV =Nipple @ 509 MD and 508 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 440 1283 627 Subsequent to operation 0 2101 0 788 741 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory ~ Development ~ Service 5. Well Status afterwork: Oil ~" Gas (T" WDSPL Daily Report of Well Operations X GSTOR ~ WAG ~ GASINJ ~ WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-061 contact -Bob Christensen/Darrell Humphrey Printed Name R be . Christe en Title Production Engineering Specialist Signature -~~hone:659-7535 Date ~® ~~ v v ~~~ ~ y~z~.o Y~J~e~ Form 10-404 Revised 7/2009 RBDMS APR , 2 20~ Submit Original Only • • 1 J-170 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/05/10 Conversion WINJ to WAG r KUP 1J-170 ~,, ~ Phi{li C TD onoco ~• ps Alalsk~t, Intr. Attribute Wellbore API/UWI s Field Name An le & MD Well Status Incl (°) MD (ttKBJ Act Btm (ftKB) 500292331000 WEST SAK INJ 92.2 3 8,139.31 12,479.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date SSSV:NIPPLE 0 7/1/2008 LastWO: 31.31 6/29/2006 wellcann~-u-nosizsrzoo9 ,o-~<-.~w _ Schemata-Actual -- __- -~ ~ Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: Show Sleeve @ 6309' Closed Imosbor 5/25/2009 Casin Stria s HANGER, 23 Casing Description String 0... String ID .. . Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd - 'I' "~--- --- CONDUCTOR 20 19.124 28.0 108.0 108.0 94.00 H-40 WELDED Casing Description String O._ String ID . _ Top (ttKBJ Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd _.,. SURFACE 103/4 9.950 30.2 3,041.1 2,146.5 45.50 L-80 BTC --- Casing Description String 0... String ID .. . Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd INTERMEDIATE 75/8 6.875 27.1 7,894.0 3,651.6 29.70 L-80 Buttress Thread Casing Description String 0... String ID .. . Top (ftKB) Set Depth (f... Set Depth (ND) .., String Wt... String ... String Top Thrtl B Lateral LEM 4 1/2 4.000 6,491.4 6,973.6 3,506.3 11.60 L-80 Casing Description String 0... String ID .. . Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... Stang ... String Top Thrd CONDU280 9 LINER A-Sand 4 1/2 4.000 6,931.0 12,470.0 3,701.2 11.60 L-80 Buttress Thread NIPPLE. s09 Liner Details Top Depin ', f (ND) Too mpl GAS GAS L 5, B Ls taaaFLoM, ~ ' _ I ~(ND) ••. ToP Incl 10,890-1 51 11,657-1 SI 12,ns-1 0 ROLLERS, 3 ROLER AXELS -LOST 3/17/2007 BELOW DIVERTER -EXACT LOCATION UNKNOWN Perforations 8 Slots Top (ftKB) Btm (ftKB) Top (ND) (ftKB) Btm (ND) (ftKB) Zone Date Shot Dens (sh.,. Type Comment 7,896 7,980 3,651.5 3,653.1 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS =Alternating slotted/solid pipe 0.125" x 2.5" x 32 spf 8,281 9,000 3,653.6 3,651.3 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS = 4 Circumferential adjacent rows 9,258 9,732 3,652.9 3,650.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS =Centers staggered 18 deg., 3 ft. non-slotted ends 10,030 10,590 3,649.0 3,647.6 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS = same as above 10,890 11,354 3,651.2 3,657.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS =same as above 11,657 12,003 3,665.0 3,673.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS =same as above 12,175 12.435 3.678.4 3.699.5 WS A2, 1J-170 6/9/2006 32.0 SLOTS ALL SLOTS =same as above (ftKB) Incl OD Valve Latch Size 7R0 Run Stn Teo IkKB1 ( ) (~) Make Medel (In) Serv TYPe Type (in) (psi) Run Date Cam... 20" 91.5# x 34" Insulated Conductor, K-55, set at +/- 80' 11" x 5" Vetco Gray MB 228 Wellhead Tubing, Special Drift to +l- 500' MD 506' MD - 3.875" DB Nipple, for Possible SSSV 3604' MD -GLM, Camco KBG-2, 4-112" X 1" 5175' MD -GLM, Camco KBG-2, 4-112" X 1" 10-314", 45.5#, BTC ~ ___- - -- 6308' MD - CMD Sliding Sleeve, w/ 3.81" DB Nipple Shoe set LID 3018' MD, e 2145' TVD, 66 deg ~ 6371' MD -Casing Sealbore Receptacle, 20' Tubing String 4-1/2" 12.6#, L-80, IBTM - ~~ _ _ - Length " " 6396' MD -Lateral Entry Module(LEM) 3.958 ID, 3.833 Drift i ~ ~ D-sand window 'D' San d Lateral - 6353' MD -5-112" X 7518" Seal j Assembly /at 6409' MD, 3413' TVD 4-112" 11.6# LAO Slotted ZXP Liner Top Packer wl 4.75" Seal OD Liner Every Other Joint 6522' MD -Baker 5-%" ECP Hold Downs Bottom ~ ~ 4-112" Eccentric 6382' MD Guide Shoe ' ~ 4.1/2" Liner Shoe, 11.6#, L-80 BTC ' ' ' 6573' MD - 5-712" Tieback Sleeve Set ~ 12671 MD, 3499 TVD 4-112" X 7518" Seal Bores ~ Model 'B' HOOK Hanger 3.68" ID Seal 6407 MD ~ ~ 4.75" Seal OD 6497' MD - 5-112" X 7-518" ZXP / Liner Top Packer wl Hold Downs \, n Lateral Entry Module (LEM) Assembly 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 4.751oSeal ODe3 875e Seal ID 6510' MD -Casing Sealbore Receptacle 20' Length ConocoPhillips West Sak 7-5/8" Injector 1 J-170 Tri-Lateral Completion 2' MD -Lateral Entry Module(LEM) B-sand Window ~.J~ at 6584' MD, 3434' D ~ 'B' Sand Lateral '\~.~ 4-112" 11.6# LAO Slotted ~~`~~~~...JJJ Liner Every Other Joint r 3-112" Bent d-112" X 7-518" ' a e 6827 MD Seal Bon 3.66" ID Swivel __ 6896' MD - 3.562" 4-112" 12.6# Tubing -~ --- DB Nipple 3.633" Drik 3.958" ID 5-112" X 7518" ZXP Liner Top Packer ~ ~~ with Hold Downs ~11 s-vr• x 7sl Liner Hanger I Packer Assembly at`^ Flex Lock 6931' MD \ Lmer Hanger ~~ \ i 6962' MD -Casing Sealbore Receptacle, 20' Length Baker Hughes 1005. This tloeument may not be reprotluced or dlSMbuted, in whole or In part In anyfomt or by any means electronic or mechanical, Inclutling photocopying, recortlln9. or by any information storage and reMeval system now known or hereafter Invented, without written permission from Baker Hughes Inc. As Completed B XUGXES Baker Oil Tools Lateral E ntr~Module (LEMI With Div erters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installetl Installed (3.00" Lateral Drin) (2.50" ID Mainbor e Dritt) 'GS' Profile for Coil Conne<tor fRUnning/Retrieving ~~ (1.00'Length) ~ Snap In/Snap Out Positive Locating ~-~ .Back Pressure Valve - Collet (1.60' Length) Lateral Isolation - Flow Thru Swivel Seals (1.25' Length) Lateral Diverter ~ i -Hydraulic Ramp Disconnect ' Isolation/ Mainbore~~ (1.50 Length) Diverter Sleeve - GS Spear ` ~ ' ~ I (1.50' Length) Lateral Isolation 6.85 h A pprox. Seals OAL' nay be recluir rd .n highly deviated o aooliweons Iti' ooorox lenathl. 16.5' Diverter Length 78.5' Sleeve Length 12" Guide Shoe 2" Liner Shoe, 11.6#, L-80 BTC Set ~ 12550' MD, 3552' TVD Seal Assembly 4.75" Seal OD Bottom ~ 6973' MD ~~ 'A' Sand Undulating Lateral 4-112" 11.6# LAO Slotted Liner Every Other Joint 4-112" Eccentric ,Guide Shoe Eauiament Specifications 4-112" X 7-SIS" 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" Mainbore Drift, wl isolation sleeve: 2.50" Lateral DriFt, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +l- 18.5' 4-1/2" Casing Shoe, 11.6#, L-80 BTC Set ~ 12470' MD, 3702' TVD 7-5/8" Casing, L-80, B7CM, Set at ~ 7894' MD, 3649' TVD (85 deg) West Sak]318"Tr1~aMral COmpletlon-Inlecbr ; • J • L~ '~~ Y =~ ~ ~ ~ ~ ~ ~ ~ ' x° ~ ~ '. ~ e F ;~ ~ f$r~ ,.~ ~ ~~~ ~~ ~~~ ~~ ~~ ~~Ftr~. ~~~ ~~ v~~ ~~ ~~ F~~ ~~ r~ ~ ~ ~~ ~ ~ ~ , ~~ ~ r a y ~' ~' ~ ~ s ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~~~ ~ SEAN PARNEtL, GOVERNOR t ~~.x r ~ ~ t ~, ~ i; ~ ~ p~ ~ ~ ~ ~ u ~ ~; ~ ~'==~ ~ ~ ~ ~~.: ~,~~~ ~ E ~ ~ ~ ~~~ ~~ ' ~ ~_ ~ ~.. ~ ~ ~ _, ~~~ _.~ ~~ ~t~ ~~+~t~~~~~~+ u~ ~L[~-78~ ~I~ t~lsi/ Vrv-7 ~ 333 W. 7thAVENUE, SUITE 100 C~~s~i ~QA~O~ COr~IIs'S'I0~ b<? ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 e FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Unit, West Sak Pool, 1J-170 ~~ ~~ ~ Sundry Number: 309-061 ~(~ Dear Mr. Loveland: ~'~~'i~~~~ i! Ci ~,l ~.'~ ~~~~~ 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, ~ Cath P. Foerster Commissioner DATED this ~~ day of October, 2009 Encl. • ~ ~ • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ~~~~~g p~~ ANCHORAGE, ALASKA 99510-0360 ~/ ~~B ~ ~ ~Q09 s~laska ~3i~ $~ ~as t;a~~. February 13, 2009 ~~~~~5~~ Anchor~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Trilateral West Sak injection well 1J-170 (206-062), 1J-170L1 (206-063), 1J-170L2 (206-064) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ~'~` ~ ~: - %~i'~!~ `;~~-` MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures G~ ~ • ~~~ ~°° ~ ~ ~ ° ~~\ STATE OF ALASKA ~~~ ~"~ 2OOg ALASKA OIL AND GAS CONSERVATION COMMISSION ~b'~~ APPLICATION FOR SUNDRY APPRC~~~'.1i~ ~ r~~ ~~n~° ~°m~"S$'on 20 AAC 25.280 ~~~~~°~~~~~ 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ~ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: 5. Permit to Drilt Nu mber: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 206-062 ' 3. Address: Stratigraphic ~ Service Q/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-00 ' 7. if pertorating, ciosest approach in pool(s) operted by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@S ^ NO ~ 1J-170 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660 & 25661 ' RKB 109' • Kuparuk River Unit/ West Sak Pool , 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12479' • 3702' • Casing Length Size MD ND Burst Collapse CONDUCTOR g0 20" 108 108' SURFACE 3013 10-3/4" 3041 2146' Intermediate 7866 7-5/8" 78g4 3649' A sand Liner 5486 4.5" 12470 3701' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted & Blank liner fr 7896-12434 3650-3700' 4.5" L-80 6382.65' Packers and SSSV Type: Packers and SSSV MD (ft) Packer - Seal assy, ZXP liner top 6360, 6931 No SSSV - Nipple 508 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 r~ { / 16. Well Status after proposed work: Commencing Operations: 7/ ~/ ~/ 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: Perry Klein/MJ Loveland Printed Name MJ Lovelan er KI ~ Title: Well Integrity Project Supervisor Signature ,~ ..~~ ~ Phone 659-7043 Date ~~ p Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representa tive may witness ~ g~ (,(1 Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other. ~i(~~irn•e.~c operc.~~'~oti ~~ a.cc.or~ ~..~i`~ /4jb Z[~a~T Subsequent Form Required: C• ~ ~"' `~'~ ~ APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: ~~ "Q Form 10-403 R ised 0¢/2W8 ' ¢ `t ~~~ bm~ i~ ~icate g ... 6 ~ @ ~' 1 ~ s`~ ~ ~ .`7.l~ ~i'~7•~ ~ 1 J-170 ~ DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. 1J-170 (PTD 206-062) & 1J-170L1 (PTD 206-063) & 1J-170L2 (PTD 206-064) Sundry Notice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in West Sak Injection Well 1J-170 and gain approval to do so. This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of VRWAG to West Sak for a potential future project to expand EOR on a broader ~ scale. See attached pattern map. Well History: 1 J-170 was drilled and completed in June 2006 as a pre produced trilateral ~ injection well and converted to a water only injector in October September 2006 The well was drilled with a 20" conductor to 108'. The surface hole was drilled with a 13.5"" bit and cased with 10-3/4"" casing to a TD of 3041'. The casing was cemented in place with 462 bbl of lead cement (Arctic set) and 79.5 bbl of tail cement (Deepcrete). Bumped plug on calculated displacement volume and the floats held. Good cement returns were seen, 120 bbl to surface. The intermediate hole was drilled with a 9-7/8" bit and cased to 7894' with 7 5/8" casing. The casing was cemented in place with 185 bbl Deepcrete cement. Bumped plug on calculated volume and good returns were mentioned. The top of cement is confirmed at 3036' by a USIT 1og. The USIT log also shows good bond through and above the West Sak and Ugnu intervals. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. Inject VRWAG cycles into 1J-170 2. Injection well 1J-170 will be operated and maintained in compliance with 20 AAC 25 and Area lnjection Order 2B. 3. All West Sak wells with in '/4 mile of 1 J-170 will be completed (or recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oil and gas samples from the offset West Sak producers. 5. All Kuparuk wells with in '/4 mile will have OA pressure indicating transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. ~ ~. ~ ~ 1 E-102 - ~ .i" i 2009 WSAK EOR ; ~ ~'~ Pattern Targets ,. ~~ y _ d ~ 1J-170 ~ ~ ; ~ r'~ ~ '~ {~ . _ ~ ~, ~~ ~ , .~ ~ - ~~ ; ~ ~ ._ ---___.,i~ _ . .. __,~ 1J-122 ~ ',,: 1Kf^ h#a~oF '' akny FauMa wS Fa~rts • GL Prpdut,-,er • Pr~oduoet • S1 Producar - P ar-r! A ~ In~ct~Ctr ~i 1E-102 1d4 rn• BufMe~ ~, . l Row tf4 m~ Bufysr --- N Ro~r~r 1/4 rn~ 6uflyfr __._ _ d Row 1JA m~ Bu/fOt Qnllgltt+ 801~ls43ly CJ • 1J-170 Cement Log Gas? Interval Top interval 5,924-5,742 3,135-2,954 Tops GASR ~MDR UG C 4,57~ UG B 5,06~ UG A 5,34E K13 5,73E D 6,41 C rn c ~~ W C G~ wz ~C i s •Interval between 6,920' and 2,950' logged • "micro" debonded near shoe • •"Micro" debonded pattern continues upwards but improves slightly •Top of cement on log @3036' •570' of cumulative cement bond with 0-20% "micro" debonding ~ ~~ u ~ Bottom interval 6,924-6,750 ~ u ~orr~ati~n~ ~n ~~v~ ~~t~l~ r~~k ~°~ ~~~~n r~~~~r~ ~~ ~~~ ~ ~r w II pe~ tr~t~ons w~th~n u~ er mil~ r~~i~~ ~I~ ~~~ ~~wt~red annular pres~ures ~~(~~ ~~! ;~Oi~ V~lel! Integrity Review with AOGCC J Jan~rarys ~ ~i , 20t1~ ~ ConocoPhillips 1J-170 Pattern •1 J-168, 1 J-10 and 1 J-166,1 E-105 all fall within '/4 mile ap •Minimal risk of any gas impacting 1 D-127 due to fault sealin~ i and in~ector offset to the north and direct capture with 1 J 16G •1 J-170-570' of cumulative good cement bond •Injection into the A and D sands only-B sand isolated •1 J-166,1 J-168,1 E-126 GL completions with packers •1 J-10-Surface casing set below the West Sak-Cemented to surface-good returns •Well will have monitored OA upon start up ~ 2009 WS Ec~R Well Integrity Review with AOGCC January 21, 2009 6 ~ ~ ~009 WS ~OR Weil Integrity Review with AOGCC 7 January 21, 2009 ~~~ ConocoPhilli ~s Bottom interval Gas?lnterval 6,924-6,750 5,924-5,742 • "micro" debonded near shoe •"Micro" debonded pattern continues upwards but improves slightly •Top of cement on log @3036' •570' of cumulative cement bond with 0-20% "micro" debonding 2009 WS EOR Well Integrity Review with AOGCC 1J-170 Cement Top interval 3,135-2,954 Log Tops UG C UG B UG A K13 D 4,574 5,063 5,346 5,736 6,41 C ~ c~ _~ ~ W ~ ~ ~ P~ u ~ January 21, 2009 ~ ~ •Interval betweEn 6,920' and 2,950' logged ~ -- ~~ ~ ~~~~~~ ~~~~~a~~ ~~~~~a~~~~ ~~°~ ~~~°~~r~~w~ ~~ ~i~M ~~ ~r~r ~ ~ ~~ ~~ ~~ ~~~~I~t~~~~ ~~th ~~~~~r~ ~~f~r~ ~N ~t~~~ ~ ~~ ~~~~~ :'~7t~~ ~l~~ t;~3#~ ~/el~il ~~~~~rity ~~vi~w ~rvvith A~C~~~ h~ .i~r~tl~~r~ f'1 ;~.~~}4~ b/ . . ConocoPh~ll~ps 1J-170 Pattern •1 J-168, 1 J-10 and 1 J-166,1 E-105 all fall within '/4 mile ap ~,~; ~.~ •Minimal risk of any gas impacting 1 D-127 due to fault sealing i and in~ector offset to the north and direct capture with 1 J-16C •1 J-170-570' of cumulative good cement bond •Injection into the A and D sands only-B sand isolated • 1 J-166,1 J-168,1 E-126 GL completions with packers •1 J-10-Surface casing set below the West Sak-Cemented to surface-good returns •Well will have monitored OA upon start up ~ 2009 WS Ec~R Well Integrity Review with AOGCC January 21, 2009 6 _ ~ ~ ~~~~~~~'hrli~p~ 1 ~l~1 ~Q Injector-Cement Details b~ ` ~ ~~~ ,~k ~TM ~ p. ~{:ed k'.a.k` a • 2UQ9 WS ~OR Well Integrity Review with AOGCC January 21, 2009 7 ~~ ConocoPhilli ~s Bottom interval Gas?lnterval 6, 924-6, 750 5, 924-5, 742 • "micro" debonded near shoe •"Micro" debonded pattern continues upwards but improves slightly •Top of cement on log @3036' •570' of cumulative cement bond with 0-20% "micro" debonding 2009 WS EOR Well Integrity Review with AOGCC 1J-170 Cement Top interval 3,135-2,954 Log Tops UG C UG B UGA K13 D 8 4,574 5, 06? 5,34E 5,73E 6,41 C ~ ~ _~ ac W ~ ~ ~ ~~ u ~ January 21, 2009 ~ ~ •Interval between 6,920' and 2,950' logged n ~ MEMORANDUM To: Jim Regg ~ / P.I. Supervisor ~~C( Zl Z~°~~ FROM: Chuck Scheve Petroteum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-170 KUPARiJK RN U WSAK 1J-170 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~~- Comm Well Name: KUPARUK RIV U WSAK iJ-170 Insp Num: mitCS090605071115 Rel Insp Num: API Well Number: 50-029-23310-00-00 Permit Number: 206-062-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/4/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11 ~J-i~o Type Inj. w~ TVD 339z ` ~oo zszs ~ zsoo zsoo ~~ P.T.D 2060620 TypeTest SPT Test psi lsoo ~X OA 16s zzo ~9s iso Interval 4YRTST P~' P ~ Tubing 630 630 630 630 NOtes: Pretest pressures observed and found stable . ' ~.~R'~','.:".' ~.?i, . ~} ~~7~~~ Wednesday, June 10, 2009 Page 1 of 1 ~~i~~~~~~~~~ NO. 5314 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth t- i ~.'`%. b~'~'::,.~ f-~is`u :' l ~~~~`; r 07/17/09 Company: Alaska Oil & Gas Gons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~Ne~~ Job # Log Description Date BL Color CD • ~ ,,, ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Regg, James B (DOA) From: NSK DHD Tech [n1656@conocophillips.com] Sent: Sunday, May 24, 2009 12:46 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Attachments: 1J-170 90 day TIO plot.png; 1J-170.pdf Page 1 of 1 (~ ?..~h~ C?~ ~ Jim Kuparuk Water injector 1J-170 (PTD 206-6~@2j is suspected of having TxIA due to the fluid volume pumped during the state witnessed MITIA today. The well will be shut in and freeze p o eF~c~ed. -The well will be added to the monthly report and DHD will perform diagnostics. 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. «1J-170 90 day TIO plot.png» «1J-170.pdf» 5/26/2009 KRU 1J-170 PTD 206-062 5/24/2009 TIO Pressures =rl' '~~ KRU 1J-170 ~ Cono~t~P~ril~ip~ ,~-laska, ~~~. TUBING (0-6383, Ir ~~.{ 3 I -- OD:4.500, ID:3 958) ~ ~j' { I ~ a,~ ~ t ~ ~~ -~ ~ ~ i ~~d - - -~:.~] ~. IC~I . ~i~ '- ~ i ~ {. SBR (D)(6372-6373, w-. ;• a I OD:6.2B0) ~ ~ { '~ ~+' ~ ~~ ~} ~ I I INTERMEDIATE I (0-7894, OD:7.625, wrzs.7o) ~ ~ r ~ _ T, i PUP (8)(6532-6813, f~ t---• OD:5.210) ,. ~,~ ~ ~' ]~I A-SAND LINER -• (4703-12550, OD:4.500, Wta1.60) 1 1 I r ~~ - ~~F ~~;. ~ 1 ~ i~ SBE (A) (6963-6964, ~ ! - OD6.260) 'I , I ~ ~ Ped 0ess-7seo) '; Pert (8281-9000) ~... ,, Pert (9258-9732) -- I __ , , _ Perl (10030.10590) ---_- I. --- ~ ~ Pert (10890-11354) --- I -- - 1. - Parf (i t657-12003) '.. ~ 1 Perf (12175.12435) --- 'I --- 1 J-170 API: 500292331000 Well T e: PROD An le TS: de SSSV T e: NIPPLE Ori Com letion: 6/29/2006 An le TD: 87 de 12479 Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo 28' RKB Ref Lo Date: Last U date: 7/20/2006 Last Ta TD: 12550 ftK6 Last Ta Date: Max Hole An le: 92 de 8139 _ Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.60 H-40 WELDED SURFACE 10.750 0 3041 2147 45.50 L-80 BTC INTERMEDIATE 7.625 0 7894 3649 29.70 L-80 BTCM A-SAND LINER 4.500 4703 12550 12550 11.60 L-80 BTC L2 WINDOW 8.000 6409 6410 3401 0.00 L1 WINDOW 8.000 6840 6841 3480 0.00 Tubin String -TUBING Size To Bottom TVD Wt Grade Thread 4.500 0 6383 3396 12.60 L-80 IBTM Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7896 - 7980 3649 - 3654 WS A2 84 32 6/9/2006 SLOTS Alternatin slotted/solid i e 8281 - 9000 3654 - 3651 WS A2 719 32 6/9/2006 SLOTS Alternatin slotted/solid i e 9258 - 9732 3653 - 3651 WS A2 474 32 6/9/2006 SLOTS Alternatin slotted/solid i e 10030 - 10590 3649 - 3646 WS A2 560 32 6/9/2006 SLOTS Alternatin slottedlsolid i e 10890 - 11354 3651 - 3658 WS A2 464 32 6/9/2006 SLOTS Alternatin slotted/solid i e 11657 - 12003 3665 - 3672 WS A2 346 32 6/9/2006 SLOTS Alternatin slotted/solid i e 12175 - 12435 3680 - 3699 WS A2 260 32 6!9/2006 SLOTS Alternatin slotted/solid i e Gas Lift'MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3604 2394 CAMCO KBG-2-1R GLV 1.0 BK-5 0.188 1502 7/14/2006 2 5175 3052 CAMCO KBG-2-1R OV 1.0 BK-5 0.313 0 7/14/2006 Other lu s, a ui ., etc'. -COMPLETION De th TVD T e Descri tion ID 22 22 HANGER VETCO GRAY TUBING HANGER 4.500 509 508 NIP CAMCO'DB-6' NO GO NIPPLE 3.875 6309 3382 SLEEVE-O BAKER CMD SLIDING SLEEVE w/CAMCO 3.81"'DB' PROFILE OPEN 3.812 6358 3392 LOCATOR BAKER GBH-22 LOCATOR SPACED OUT 4' ABOVE FULLY INSERTED 3.875 6360 3392 SEAL BAKER SBE SEAL ASSEMBLY 3.875 6382 3396 SHOE 3.958 Other lu s, a ui .etc. -"D-SAND. & B-SAND LEMs De th TVD T e Descri tion ID 6353 3391 PACKER D ZXP LINER TOP PACKER 4.950 6372 3394 SBR D 190-47 CASING SEAL BORE RECEPTACLE 4.750 6392 3398 BUSHING D CROSSOVER BUSHING 3.950 6394 3398 PUP D PUP 3.958 6397 3399 HANGER D ABOVE HOOK HANGER 3.980 6407 3401 HANGER D INSIDE HOOK HANGER 3.980 6491 3417 PACKER B ZXP LINER TOP PACKER 4.950 6510 3420 SBR B 109-47 CASING SEAL BORE RECEPTACLE 4.750 6530 3424 BUSHING B CROSSOVER BUSHING 3.950 6532 3424 PUP B PUP 3.958 6813 3475 HANGER B ABOVE HOOK HANGER 3.980 6823 3477 HANGER B INSIDE HOOK HANGER 3.980 Other lu s, a ui ., etc. - A-SAND LINER'DETAIL De th TVD T e Descri tion ID 6931 3498 PACKER A HRD ZXP LINER TOP PACKER 5.500 6950 3501 NIPPLE A RS PACKOFF SEAL NIPPLE 4.870 6953 3502 HANGER A FLEXLOCK LINER HANGER 5.510 6963 3504 SBE A 190-47 CASING SEAL BORE EXTENSION 4.750 6982 3507 BUSHING (A) CROSSOVER BUSHING 3.930 General Notes Date Note 7/1/2006 MULTI-LATERAL WELL: 1J-170 (A-SAND), 1J-170L1 (B-SAND), 1J-170L2 (D-SAND) TREE: VETCO GRAY / HORZ / 4 1/8" 5M -TREE CAP CONNECTION: 9.5" OTIS MEMORANDUM Toy Jim Re 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-170 KUPARUK RIV U WSAK 1J-170 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RN U WSAK 1J-170 API Well Number: 50-029-23310-00-00 Inspector Name: Bob Noble Insp Num: mitRCN090526120834 Permit Number: 206-062-0 Inspection Date: 5/24/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 1J-t7o - Type Inj. W TVD 3392 IA 900 P.T.D zo6o6zo ~ TypeTest sPT Test psi ]soo OA 16z Interval 4YRTST per, F ~ Tubing 668 Notes: Pumped 11.5 bbls and psi did not build up. s~ Z~-~~ Wednesday, May 27, 2009 Page 1 of 1 C ~/ onocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • • ao6~ 06~- ~~'~~° 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. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, 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. 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) Kuparuk Field f1..4.. 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 1F-18A 204-167 15' 5" 2.50 44" 10/30/2008 27.2 11/7/2008 1E-168 204-200 15" NA 15" NA 3.4 11/7/2008 1E-17 205-074 13" NA 13" NA 5.53 11/7/2008 1J-122 207-070 15" NA 15" NA 3.4 11/7/2008 1J-14 200-200 16" NA 16" NA 1.27 11/7/2008 1 J-152 206-016 3' NA 3' NA 19.55 11/17/2008 1J-158 207-054 6' NA 6' NA 27.2 11/7/2008 1J-162 2 7-080 15" NA 15" NA 2.55 11R/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1 J-170 206-062 8" NA 8" NA 1 11 /7/2008 1J-174 207-143 24" NA 24" NA 17 11/7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 _ _ ___ Page 1 of ~~ • Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com] Sent: Thursday, October 30, 2008 9:51 AM To: Maunder, Thomas E (DOA) Cc: Targac, Gary; NSK Welf Integrity Proj Subject: RE: 206-062_1J-170_404_2008_0821.pdf Tom, I appreciate you taking the time to point out the discrepancy. I will endeavor to assure that the correct information is entered. Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) This email may contain confidential information. If you receive this a-mail in error, please notify the sender and delete this email immediately. From: NSK Well Integrity Proj Sent: Monday, October 27, 2008 2:57 PM To: NSK Prod Engr Specialist Cc: Targac, Gary Subject: FW: 206-062_iJ-170_404_2008_0821.pdf Bob, Please review the information from Tom below. MJ Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Mon ctober 27, 2008 2:23 PM To: NSK Well Integra Ce: Fleckenstein, Robert J (D g, James B (DOA) Subject:206-062_iJ-170_404_2008_ f MJ, I am sending this just to you since I don't seem to I~ ob Chri Please forward. The reason for this note is regard' ,l-t1'~ depth fisted for the packer in this service well. 'I'treFe was considerable effort expended determin' a packer or sealing element depth that establishes the bottom oft r injecti~ wells. 1 believe t oblem Wells performed a lot of work on that project. When 404s are submitted for i skit wells, on a cross checks performed is to compare the packer depth listed on the new document with the depth in the AOGCC record. If work has been accomplished that would change the packer depth, the record is revised. However in cases such as this where the work performed would not have affected the packer 11/5/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sen#: Monday, October 27, 2008 2:23 PM To: 'NSK Well Integrity Proj' Cc: Fleckenstein, Robert J (DOA); Regg, James B (DOA) Subject: 206-062_1 J-170_404_2008_0$21.pdf Attachments: 206-062_1J-170_404 2008_0$21.pdf • MJ, I am sending this just to you since I don't seem to have Bob Christensen's email. Please forward. The reason for this note is regarding the depth listed for the packer in this service wail. There was considerable effort expended determining the packer or sealing element depth that establishes the bottom of the iA for injection wells. I believe that Problem Wells performed a lot of work on that project. When 404s are submitted for injection wells, one of the cross checks performed is to compare the packer depth listed on the new document with the packer depth in the AOGCG record. if work has been accomplished that would change the packer depth, the record is revised. However in cases such as this where the work performed would not have affected the packer depth and a depth change is noted, messages such as this result. In this particular well, the depth in our "packer record" is 6360' and which according to the drawing provided with the completion report is the depth of the seal assembly. The packer depth given on this 404 is 6383' and which might be the middle of the seal bore receptacle. In order to reduce the need for messages like this, it would be appreciated that the established "packer" depth be what is listed on documents where the work has not physically altered the setting depth. Please share this with your colleagues. Call or message with any questions. Tom Maunder, PE AOGCC 10/27/2008 ConocoPhillips Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 ~~~~~ F7314 BUG 2 6 2i~~` August 21, 2007 Alaska Oil & Gas Coss. ¢~~~~~-~s,.i,J.:, Ancho~~~~ Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission ~~ ~ Cd~ 33 W. 7`~ Ave. Ste. 100 ~~ Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set a blanking sleeve in the Lateral Entry Module (LEM) of one West Sak multilateral injection well. Enclosed you will find 10-404 Reports of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1J-170, 1 J-170L1, and 1 J-170L2. These reports record the setting of an LEM isolation sleeve in the L1 lateral water injection well. If you have any questions regarding this matter, please contact myself at 659-7535. Sincerely, ~~ Robert D. Chistensen Attachments ~ ~~~I AUG 2 6 „_;' LJi;c) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS~~ k8 ®ll & G8S ~~~;;~;~, ~,~,~,i;,;~„r,n REPORT OF SUNDRY WELL OPERA~IONS,~nc~r?~:}c~~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ et B-sand Iso Sleev Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnoCOPhilhps Alaska, InC. Development ^ Exploratory ^ 206-062 3. Address: Strati ra hic Service g p ^ ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-170 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25661 Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 12479' ~ feet true vertical 3702' feet Plugs (measured) Effective Depth measured 12468 feet Junk (measured) true vertical 3701 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3013' 10-3/4" 3041' 2147' INTERMEDIATE 3.55' 7-5/8" 7894' 3652' SLOTTED LINER 5539' 4-1/2" 12470' 3701' Perforation depth: Measured depth: 7896'-7980'; 8281'-9000'; 9258'-9732'; 10030'-10590 ; 10890'-11.354'; 11657'-12003 ; 12175'-12435' true vertical depth: 3654'-3651'; 3653'-3651'; 3649'-3648'; 3651'-3658'; .3665'-3674'; 3678'-3700' Tubing (size, grade, and measured depth) 4-1/2", L-80, 6382.65' MD. 5~ QV ~ '°Qf ~ ~~d~ ~~ o ~ ° Packers &SSSV (type & measured depth) Packer = ZXP Liner top Pkr Packer = 6,63 ; 6931' t ~c`~ ~ ~.~ ~ ,~,~ Ate. ~ l /!!// ' J i~ ~ ~ ~ ~ SSSV =NIP SSSV = 509' ~ y 7 ` ( 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~ 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 917 1564 672 Subsequent to operation 991 612 348 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen /Vacant Printed Name R be .Chris nsen Title Production Engineering Technician Signature Phone 659-7535 Date ~'/ d 02"1 ©~ i..~~ 9 " b '' S~`~ 1~ ~~-~ f/~ ~J (~ ~ o ~ 9.3.0$ Form 10-404 Revised 04/2004 Submit Orig nal ~~~~~~ ~~ '. 1J-170 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/10/08 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET. RE: LPP/SSV defeated on 1J-1~ • Page 1 of 2 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Tuesday, September 09, 2008 10:50 AM To: Maunder, Thomas E (DOA); Regg, James B (DOR) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Pierson, Chris R; NSK West Sak Prod Engr Subject: RE: LPP/SSV defeated on 1J-170 Tom /Jim, The low pressure pilot (LPP) on 1J-170 (PTS 206-062 ! 206-063 / 206-064) was put back into service on 9/8/2008. The well is currently injecting 1278 bwpd at 547 psi injection pressure. Please let me know if you have any questions. Regards, Hai Hunt a~e~l~~ SEA :~ ~ 2DD$ Hai Hunt /Eric HoNar NSK West Sak Production Engineer ConocoPhitlips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com From: NSK West Sak Prod Engr Sent: Wednesday, AugusE 13, 2008 12:18 PM 70: NSK west Sak Prod Engr; 'Maunder, Thomas E {DpA)'; 'jim.regg@alaska.gov' Cc: CPFi DS Lead Techs; CPFi Prod Supt; Targac, Gary; NSK Problem Welf Supv; Pierson, Chris R Subject: LPPJSSV defeated on 1J-170 Tom /Jim, The low pressure pilot (LPP) on 1J-170 (PTD 206-062 / 206-063 L1 / 206-064 L2) was defeated on 8/13/2008 when the well was returned to service after being shut in for wellwork. Current wellhead pressure is 223 psi; injection rate is 633 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. Regards, 9/9/2008 • ~~L ~~ ?°~.4/1/~IVIIT°T~4 ProActive Diagnostic Services, Inc. 2) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 S Fax (907) 245-8952 1 ] Injection Profile 29,Ju1-08 ~ 1 J-170 ~ 1 BL / EDE 50-029-23310.00 To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspec~don(Caliper/ MTT~ c>TC paC,-fXo2 ~' rlo~ ~~,81~~~ r~UU > 1 ~~~$ Signed Print Name: ~ns~-lia,p -IlLlsd~.~8~.~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (907)245-8851 FAx: (907)245-88952 E-MAIL ~<~a~a.~.~~ ~v.^,..~:~~~~71a~.~~s~ WEBSITE ~vrr~~„~: ~ y ,a,.~~,: Jan " C:\Documents and Settings\Owner\Desktop\'[lansmit Conoco.doc LPP/SSV defeated on 1J-170 ~ • Page 1 of 1 Maunder, Thomas E (DOAj From: NSK West Sak Prod Engr ~n1638@conocophillips.com] Sent: Wednesday, August 13, 2008 12:18 PM To: NSK West Sak Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Pierson, Chris R Subject: LPP/SSV defeated on 1 J-170 Tom /Jim, The low pressure pilot (LPP) on 1J-170 (PTD 206-062 / 206-063 L1 / 206-064 L2) was defeated on 8/13/2008 when the well was returned to service a er being shut in for wellwork. Current wellhead pressure is 223 psi; injection rate is 633 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 retumed to normal, in accordance with "Administrative Approval No. CO 4068.001 ". Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/13/2008 • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-170+PB1+PB2+L1+L2 AK-MW-4406587 July 18, 2008 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-170+PB 1+PB2+L 1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-23 310-00,60,61,70,71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-23 310-00,60,61,70 Digital Log Images 50-029-23310-00,60,61,70,~1~,~~~ AU G ~ -~ ~~~~ ~.~.~ 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage~.Alaska 995.18. Anchorage, Alaska 99508 ~. r- ~ Date: _ Signed: ~ ~ ~ /lh~ ~~ ~a. tCo°~~q a ~~.~, DATA SUBMITTAL COMPLIANCE REPORT 6/25/2008 Permit to Drill 2060620 Well Name/No. KUPARUK RIV U WSAK 1J-170 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23310-00-00 MD 12479 TVD 3702 Completion Date 6/2/2006 Completion Status 1-OIL Current Status 1WINJ 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 / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ,~'Rpt 14023 LIS Verification Open 8/22/2006 I GL~og Corrosion 5 Col 1 2950 6920 Case 6/14/2006 USIT-GR-MaxTrac CCL 11- J u n-2006 ~D C Lis 14023 Induction/Resistivity 3004 12421 Open 8/22/2006 ROP, GR, Res, FET i~pt 14023 kCfS Verification 0 0 8/22/2006 iLD C Lis 14023i~nduction/Resistivity 3004 9223 Open 8/22/2006 PB1, ROP, FET, Res, GR apt 14023 CIS Verification 0 0 8/22/2006 Lis Verification on P62 D C Lis 14023action/Resistivity 3004 11858 Open 8!22/2006 PB2 ROP, GR Res, FET D D Asc Directional Survey 11226 12479 Open 8/22/2006 D D Asc Directional Survey 0 9281 Open 8/22/2006 PB 1 ~D D Asc Directional Survey 7859 11916 Open 8/22/2006 PB 2 og Production 15 Blu 1 100 6970 Open 9/12/2006 PPL Welltec Tractor Conveyance 1-Spt-2006 ,/ log Injection Profile 5 Blu 6290 6930 Case 6/11/2007 Injection Profile welltrec tractor conveyance 24-May- 2007 Well Cores/Samples Information: S ample Interval Set Name Start Stop Sent Received N umber Comments DATA SUBMITTAL COMPLIANCE REPORT 6/25/200$ Permit to Drill 2060620 Well Name/No. KUPARUK RIV U WSAK 1J-170 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23310-00-00 MD 12479 TVD 3702 Completion Date 6/2/2006 Completion Status 1-OIL Current Status 1WINJ UIC Y ADDITIONAL INFORMATION Well Cored? Y / f~ Daily History Received? "'/ N Chips Received? `i~f~fd-+ Formation Tops Analysis Y~'-f~ Received? Gomments: --- ----- ('-'- Q Compliance Reviewed By: _________r~ Date: J AAA /~lf~'~~ O Page 1 of 2 Regg, James B (DOA) ~ ~~~ ~~~,~ From: NSK Problem Well Supv [n1617@conocophiflips.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: 1C-20.pdf; 1J-102.pdf; 1J-156.pdf; 1J-170.pdf; 1J-127.pdf; 1J-184.pdf Jim, E-lere are the schematics of the motherbores for 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 ConocoPhillips 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} -1 am still looking into whether that is a Welk 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 bare 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 ] (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 1 J-127 2060440 WSAK 1 J-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~ol?.flecken4tc.~n~ alasa.;c?v 3/12/2008 ~ ~ ~ ~ Cdsaoac~F'h~lt~rs Alaska, ins. __ 1 J-170 i~ i i I PUP (B) (6532813, OD:5.210) Perf ;10030-10590) KRU 1J-170 API: 500292331000 Well T e: INJ An le TS: d SSSV T e: NIPPLE Ori Com letion: 6/29/2006 An le TD: 87 de 12479 Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE Reference Lo 28' RKB Ref Lo Date: Last U date: 12/28/2007 Last Ta TD: 12550 ftKB Last Taq Date: Max Hole Angle: 92 deq (07 8139 ~ ~ .. ~ ~'- r ~ ,~ I is ~ '; 3 :~ r r; (;asmn STnnn -All ti I I-tIN(,5 Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.60 H-40 WELDED SURFACE 10.750 0 3041 2147 45.50 L-80 BTC INTERMEDIATE 7.625 0 7894 3649 29.70 L-80 BTCM L2 WINDOW 8.000 6409 6410 3401 0.00 L1 WINDOW 8.000 6840 6841 3480 0.00 A-SAND LINER 4.500 6931 12550 12550 11 RO 1.-sn RTC: Tubin Strin -TUBING Size ToD Bottom TVD Wt Grade Thread 4.500 0 6383 3396 12.60 L-80 IBTM Perforations Summary Interval TVD zone Status Ft SPF Date t e Comment 7896 - 7980 3649 - 3654 WS A2 84 32 6/9/2006 SLOTS Alternatin slotted/solid i e 8281 - 9000 3654 - 3651 WS A2 719 32 6/9/2006 SLOTS Alternatin slotted/solid i e 9258 - 9732 3653 - 3651 WS A2 474 32 6/9/2006 SLOTS Alternatin slotted/solid i e 10030 - 10590 3649 - 3646 WS A2 560 32 6!9/2006 SLOTS Alternatin slotted/solid i e 10890 - 11354 3651 - 3658 WS A2 464 32 6/9/2006 SLOTS Alternatin slotted/solid i e 11657 - 12003 3665 - 3672 WS A2 346 32 6!9/2006 SLOTS Alternatin slotted/solid i e 12175 - 12A35 3680 _ 3899 WS A? 280 32 R/9/2008 SLC)TS Altarnatin~ clnttart/cnlid pipe ..Gas... Lift Mandrels/Valves St MD TVD 'Man Mfr Man Type V Mfr V Type V UD Latch Port TRO Date Run Vlv Cmnt 1 3604 2394 CAMCO KBG-2-1R DMY 1.0 BK-5 0.000 0 9/22/2006 2 5175 3052 CAMCO KBG-2-1R DMY 1.0 BK-5 0.000 0 9/23/2006 Other (Dluas. eauiD.. etc.) -COMPLETION ~~ ___ _.I. _ ....... Mr ^ ' _ 1 _- i ~ ~ _ ~ ~ ~ ~ De th TVD T e Descri ion ID 22 22 HANGER VETCO GRAY TUBING HANGER 4.500 509 508 NIP CAMCO'DB-6' NO GO NIPPLE 3.875 6309 3382 SLEEVE-O BAKER CMD SLIDING SLEEVE w/CAMCO 3.81"'DB' PROFILE OPEN 3.812 6358 3392 LOCATOR BAKER GBH-22 LOCATOR SPACED OUT 4' ABOVE FULLY INSERTED 3.875 6360 3392 SEAL BAKER SBE SEAL ASSEMBLY 3.875 fi'2R2 '2898 CHnF '3 QSR Other (plugs, equip., etc. - D-SAND & B-SAND LEMs ve n 6353 ~ w 3391 i e PACKER D vescn uun D-SAND ZXP LINER TOP PACKER rv 4.950 6372 3394 SBR D D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 6392 3398 BUSHING D D-SAND CROSSOVER BUSHING 3.950 6394 3398 PUP D D-SAND PUP 3.958 6397 3399 HANGER D D-SAND ABOVE HOOK HANGER 3.980 6407 3401 HANGER D D-SAND INSIDE HOOK HANGER 3.980 6491 3417 PACKER B B-SAND ZXP LINER TOP PACKER 4.950 6510 3420 SBR B B-SAND 109-47 CASING SEAL BORE RECEPTACLE 4.750 6530 3424 XO BUSHING B B-SAND CROSSOVER BUSHING 3.950 6532 3424 PUP B B-SAND PUP 3.958 6813 3475 HANGER B B-SAND ABOVE HOOK HANGER 3.980 6823 Other ( De th 3477 plugs, TVD HANGER/Bl equip., etc T e B-SAND INSIDE HOOK HANGER .) - A-SAND LINER DETAIL Descn uon 3.980 ID 6931 3498 PACKER A A-SAND HRD ZXP LINER TOP PACKER 5.500 6950 3501 NIPPLE A A-SAND RS PACKOFF SEAL NIPPLE 4.870 6953 3502 HANGER A A-SAND FLEXLOCK LINER HANGER 5.510 6963 3504 SBE A A-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 6982 3507 BUSHING !A1 A-SAND CROSSOVER BUSHING 3.930 Fish -FISH r>~pth Description Comment -. ~-cli fi.~F-r I ~ I I 1 I~ ~.l i f CUTE LI G~ ~' 1 _ ~' L~ ~.- L_B. , ~ ~_$ ~:_ I 1 ~ a'J C I CF T~~P: E- f I I~-~~; ,ill .`. `1 06/08/07 ~C~~~~U~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # .~ , _~ ~I ,~ E~" k~~ .~a.:~. ~0 v~ ~a~- ova Log Description N0.4286 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD ~j' 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROFILDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05105107 1 1C-125 N/A MEM INJECTION PROFILE 05/05107 1 2D-13 11638861 PRODUCTION PROFILE 05/03107 1 2D-08 11638862 PRODUCTION PROFILE 05104107 1 2G-09 11638864 PRODUCTION PROFILE 05106107 1 2N-349A 11629004 RST/ WFL 05104/07 1 3H-19 11638867 PRODUCTION PROFILE 05109/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05!03/07 1 1E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT 05125/07 1 2V-08A 11629013 PMIT 05115/07 1 1J-160 11632704 PRODUCTION PROFILE 03119!07 1 1H-07 11665436 SBHP SURVEY 05/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15107 1 2Z-29 11665438 PRODUCTION PROFILE 05/22107 1 1H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y-11 11632708 INJECTION PROFILE 05/23107 1 1G-03 11637336 INJECTION PROFILE 05/74/07 1 1A-23 11665443 MEM PRODUCTION PROFILE 05/29/07 1 1 F-08 11665435 SBHP SURVEY 05/20/07 1 1J-170 11632709 INJECTION PROFILE 05124/07 1 1 D-109 NIA INJECTION PROFILE 05113/07 1 2M-24 11665440 SBHP SURVEY 05128107 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 Defeated On West Sak Injectors at DSIJ • Sabjeet: LPP Defeated On West Sak Injectors at DS1J From: NSK West Sak Prod Engr <n1638@conocophillips.com> Date: Sun, 14 Jan 2007 10:08:32 -0900 To: "Tom Maunder:" <tom_maunder~~dmin.state.ak.us>, "Jim Regg;" <jim_regg@admin.state.ak.us> CC: CPFI DS Lead Techs <nl 140@conocophilliips.com>, CPFI Prod Supt <n l 132@conocophillips.com> Tom /Jim, ~0~-~~~ 1) The Low Pressure Pilot (LPP) for 1J-164 was defeated on 1/8107 in accordance with "Administrative Approval No. CO 4068.001." The LPP and SSV have been tagged and recorded on the "Facility Defeated Safety Device Log." Wellhead pressure dropped below 500 psi on 1/8/07 after a foreign object became lodged in the restriction orifice (injection choke). The foreign object was removed on 1/13/07 (yesterday) and injection rate was returned to normal. The wellhead pressure is now 468 psi (1634 bwpd) and is building back up to where it was before the 1/8/07 event. I anticipate we wil{ need to keep the LPP defeated for ~1 week. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. 2) The Low Pressure Pilots for 1J-127, 1J-154, 1J-156, and 1J-170 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: 1J-127 1517 BWPD, 548 PSI 1J-154 1406 BWPD, 612 PSI 1J-156 3613 BWPD, 586 PSI 1J-170 2737 BWPD, 540 PSI Regards, Hai Hai Hunt /Pete Nezaticky a® S-O 3 5 ~C~ °~C7Co `"l NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 1 of 1 6/12/2007 1:32 PM From: NSK Problem WeII Supv <n 1 G 17@conocophillips.com> Date: Tue, 24 Oct 2006 16:56;1 i) -800 To: to~nmaur~der(ciadmin.state.ak.us, jim_re~g(ciadmin.stat~.ak.us, bob tlccl~enstein(n,'adrnin.state.ak.us «MIT KRU 1D 10-22-06.x1s» «MIT KRU 1J 10-22-06.x1s» All, Enclosed are the state witnessed MITIA data for the two recent surface casing repairs 1 D-109, & 1 D-120 and the initial MITIA post conversion of 1J-127, 1J-156, and 1J-170. -©~C-~~C,~-- One thing to note regarding the 1J data is that all three wells are currently on a vacuum thus the tubing pressure is listed as zero. If you have any questions let me know Perry Klein Problem Well Supervisor office (907} 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 'Content-Description: MIT KRU 1D 10-22-06.x1s ''MIT KRU 1D 10-22-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT KRU 1J 10-22-06.x1s MIT KRU 1J 10-22-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 10/30/2006 9:14 AM • STATE OF ALASKA Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ConocoPhillips Alaska Inc. Kuparuk /KRU / 1J 10/22/06 Greenwood !Noble Jeff Jones C~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-127 Type Inj. W TVD 3,482' Tubing 0 0 0 0 Interval I P.T.D. 2060470 Type test P Test psi 1500 Casing 1400 2180 2140 2140 P/F P Notes: Pre produced injectors, well on a vacuum OA 25 0 0 0 Well 1J-156 Type Inj. W TVD 3,410' Tubing 0 0 0 0 Interval I P.T.D. 2060670 Type test P Test psi 1500 Casing 750 2000 1950 1940 P/F P Notes: Pre produced injectors, well on a vacuum OA 0 0 0 0 Well 1J-170 Type Inj. W TVD 3,391' Tubing 0 0 0 0 Interval I P.T.D. 2060620 Type test P Test psi 1500 Casing 1720 2200 2170 2160 P/F P Notes: Pre produced injectors, well on a vacuum OA 150 150 150 150 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 1J 10-22-06.x1s K. m ~ ~ ~ ~ ~5£~ ~i ~ ~ .fug ~ G+ v ' STATE OF ALASKA ~ ~,,, ~jo~~8 ~` f ` ,' ~l ALASKA OIL AND GAS CONSERVATION COMMISSION ' - REPORT OF SUNDRY WELL OPERATIONS `~ - 1.Operations Performed: 'Abandon ^ Repair Well ^ Plug Perrorations ^ Stimulate ^ Other Q Prod to WIND . • Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time :Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-062 / ' 3. Address: Strati ra hic Service ~ g p ^ ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510. 50-029-23310-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-170 8. Property Designation: 10. FieldlPool(s): ADL 25660, 25661 ' Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12479' feet ~• true vertical 3702' feet Plugs (measured) Effective Depth measured 12468 feet Junk (measured) true vertical 3701 feet Casing Length Size MD TVD Burst Collapse Structural - CONDUCTOR 108' 20" 108' 108' SURFACE 2932' 10-3/4" 3041' 2146' L2 WINDOW ~ 1' 7-5/8" 6410' 3401' L1 WINDOW 1' 7-5/8" 6841' 3480' INTERMEDIATE 7785' 7-5/8" 7894' Perforation depth: Measured depth: Slotted Liner 7896'-12435' true vertical depth: 3650'-3700' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6383' MD. Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 509' 12. Stimulation or cement squeeze summary: ~ ~ ~ ~~~ # ~.. - ~7 ~ Intervals treated (measured) ° ' ~j! ~ 7a~6 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 2206 4003 3 .1269 222 Subsequent to operation 21 875 1612 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 • Daily Report of Well Operations _X 16. Well Status after proposed 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 NiA if C.O. Exempt • 306-294 :contact Bob Christensen /:Bob Buchholz Printed Name b D.. hr sen Title Pi-odtaction °Engineering Technician .Signature Phone 659-7535 Date/© / C ! ~~`5G' w ~~ 23~G ' ~L Form 10-404 Revised D4/2004 1 I !-O ^ I ~ ~ ( Submit Ori ' 10~~~~~,. • 1J-170 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/09/06 Well shut in-for Producer to Injector conversion ' 10/02/06 Commenced Water Injection Service West Sak Injector 1 J-170 : Notification of Defeated Low Pressure Pil... • • Subject: West Sak Injector 1J-170 : Notification of Defeated Ldw Pressure?Pilot (LPP) From: NSK West Sak Prod Engr <n1638@conocophillips.com Date: Mon, 16 Oct 2006 17:11:10 -0800 To: to~ni~~aunderra?.adinin.staic.ak.us, jimrc~~~~ru::ndmin.staic.ak.us CC: NSK West Sak Prod Ens~r ~n16>~(c1?co~~ocophillips.corll=~ Tom /Jim, This email is to notify the AOGCC that the (West Sak Injector) 1J-170 Low Pressure Pilot (LPP) is defeated as of 10/15/06. This is 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." 1J-170 was brought online October 15, 2006. Current injection rate is 1250 bwpd; injection pressure at the wellhead is -40 psig. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 1 of I E~7~`~r~h~ J ~~ n~rV 11/2/2006 3:33 PM ~V~~ Si.P 7 z ?~Oo Schtu~m6erger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~) /~ J- NO. 3955 vii & Gas Cens. CC~T',(TiISSICr ~~nct~crace 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 09/11 /06 2M-35 11213795 LDL 08/16/06 1 1Y-24A 11213786 SBHP 07!25/O6 1 2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1 1D-O6 11249948 INJECTION PROFILE 08/26/06 1 1A-10 11216318 INJECTION PROFILE 08/28106 1 1J-184 11249951 PRODUCTION PROFILE 08/29/06 1 1J-127 11249953 PRODUCTION PROFILE 08/31/06 1 1J-170 11249954 PRODUCTION PROFILE 09/01/O6 1 1G-04 11216321 INJECTION PROFILE 08/31/06 1 1D-12 11216322 PRODUCTION PROFILE 09/01/06 1 2F-O6 11216320 FLOWING BHP SURVEY 08/30/06 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • d ' FRANK H MURKOWSKI G ~ ~, ~, ~~ , r ~ ~ . , OVERNOR ~A ~~ _~ ~~ ~~++ _* ~ 1~ ~r ~ ~ ~7~ O~ ~ ~ r y "' C011TSERQA'rI011T COhil~'IISSI011T 333 W. 7 AVENUE, SUITE 100 ;`~ ANCHORAGE, ALASKA 99501-3539 ; PHONE (907) 279-1433 Robert Christensen FAx (90~ 27r>7542 Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-170 Sundry Number: 306-294 Dear Mr. Christensen: 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. DATED this lay of September, 2006 Encl. ;'~'t%(c y~'Cc~ Sincerely. • ConocoPhillips August 26, 2006 Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 DECEIVED AU G 2 9 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Subject: Sundry Applications for Proposed Change of Well Class. Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Sundry Applications for Proposed ~ Change of Well Class on West Sak wells 1J-170, 1J-170L1, and 1J-170L2. If you have any questions regarding this matter, please contact me or Robert Buchholz at 659-7535. Robert D. Christensen • Attachments: 10-403 Form T_~ STATE OF ALASKA ~~x, RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 9 2006 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Q 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ WaiverA~C~.a9e Other O Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ C.Ow~~-~ ~o Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 4~ha<=c~aC~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 206-062 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-00 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 changes: Spacing Exception Required? YeS NO ~ 1J-170 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660, 25661 RKB 109' 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): 12479' 3702' 12468 3701 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2932' 10-3/4" 3041' 2146' L2 WINDOW 1' 7-5/8" 6410' 3401' L1 WINDOW 1' 7-5/8" 6841' 3480' INTERMEDIATE 7785' 7-5/8" 7894' 3650' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner7896'-12435' 3650'-3700 4-1/2" L-80 6383' Packers and SSSV Type: Packers and SSSV MD (ft) no packer 5r~,c.~~ b~~ G'-6~~~~ SSSV= NIP SSSV= 509' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after prgposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ;^ Service 15, Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 1, 2006 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 obey D Christen n Title: Production Engineering Technician Signature ~--_..- _ _,Phone 659-7535 Date ~~O B(p Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other. ~~I~S ~F~_, s~P ~ ~ 2oos Subsequent Form Required: "'1~ L\ APPROVED BY Approved by: OMMISSIONER THE COMMISSION ~-~~ i Date: Form 10-403 Revised 06/2qf~ n ~ ~ I ~ ~ ~ Submit in Duplicate ~~ ~ ~~~~~ • 1 J-170 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1 J-170. This well was pre-produced fora 64 day period in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-170 will provide pressure ~ support for the West Sak A sands. The 10-3/4" Surface casing (3041' and / 2146' tvd) was cemented with 560 sx AS Lite followed by 180 sx DeepCrete. The 7-5/8" Intermediate casing (7894' and / 3649' tvd) was cemented with 460 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 6353' and / 3391' tvd. This well also contains a Lower A sand 5-1/2" x 7-5/8" ZXP Liner Top Packer w / HRD located @ 6931' and / 3498' tvd. The top of West Sak D sand was found at 6410' and / 3401' tvd. ~ The top of West Sak B sand was found at 6826' and / 3478' tvd. The top of West Sak A sand was found at 7829' and / 3645' tvd. • ~' KRU 1 J-170 ..: ~r~~acc~hitl~ps ,~,I~s~~l, lr~~> 1J-170 Tueuactos3e3 API: 500292331000 Well Type: ~ PROD Angle (D TS: i deg ~ coaooo,b3~el B ~ ~'": !a-----~-----~'~"~ ~ E~ I SSSV Twe: NIPPLE Oria Completion: 629/2006 Anale rc~ TD 87 dea frD 12479 Casing Strin~ALL STRINGS __ Description ~ Size Top ~ Bottom ~D ~ Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.60 H-40 WELDED L2 WINDOW 8.000 6409 6410 3401 0.00 L1 WINDOW 8.000 6840 6841 3480 0.00 _ _ -".- Tubin String -TUBING __ ~ _ - ___ --- Size _ T~__ Bottom 4_ TVD Wt Grade Thread 4.500 0 6383 i 3396 ! 12.60 L-80 IBTM - - __ P f ti S seR(~iea~z.~~3 ~~,. er ora ons ummar~r_ -- _ , o~ezeol r Interval TVD Zone Status Ft SPF Date T e Comment 7896 - 7980 3649 - 3654 WS A2 84 32 6/92006 SLOTS Alternatin slotted/solid i e '"`' .. 8281 - 9000 3654 - 3651 WS A2 719 32 6192006 SLOTS Alternatin slotted/solid i e E ','' 9258 - 9732 3653 - 3651 WS A2 474 32 6/92006 SLOTS Alternatin slotted/solid i e 1 10030 - 10590 3649 - 3646 WS A2 560 32 6/92006 SLOTS Alternatin slotted/solid i e " ' : ` 10890 - 11354 3651 - 3658 WS A2 464 32 6/92006 SLOTS Alternatin slotted/solid i e -~ 11657 - 12003 3665 - 3672 WS A2 346 32 6/92006 SLOTS Alternating slotted/solid i e .: t"- > 12175 - 12435 3680 - 3699 WS A2 260 32 6/92006 SLOTS Alternating slottedlsolid pipe Gas Lift Mandrels/Valves _ - _ T~ -- - St MD TVD Man Man T e V Mfr V T yp ype V OD Latch Port TRO Date Run Vlv Mfr Cmnt <E<: 1 3604 2394 CAMCO KBG-2-1R GLV 1.0 BK-5 0.188 1502 7/142006 rrearvroinTe o ~esa oo~sz~ ] I ` 2 5175 3052, CAMCO er u 5 T e De th TVD ~ equip., et KBG-2-1R OV 10 BK-5 0313 0 7/142006 c.) -COMPLETION --- - Descri ion ID i - , , w~ zs col ;: 22 22 HANGER VETCO GRAY TUBING HANGER 4.500 ~::::::1:;: 509 508 NIP CAMCO'DB-6' NO GO NIPPLE 3.875 6309 3382 SLEEVE-O BAKER CMD SLIDING SLEEVE w/CAMCO 3.81"'DB' PROFILE OPEN 3.812 6358 3392 LOCATOR BAKER GBH-22 LOCATOR SPACED OUT 4' ABOVE FULLY INSERTED 3.875 6360 3392 SEAL BAKER SBE SEAL ASSEMBLY 3.875 • '' 6382 3396 SHOE 3.958 ' "' " , Other - - - - -- __ lu s, equip.,_etc.)_ D-SAND 8~ B-SAND LEMs -- _ -- - _ - ~7 De h TVD T e Descri lion ID ~ " N 6353 3391 PACKER D ZXP LINER TOP PACKER 4.950 6372 3394 SBR D 190-47 CASING SEAL BORE RECEPTACLE 4.750 ~: 6392 3398 BUSHING D CROSSOVER BUSHING 3.950 le~~zee,~ wPis I 6394 3398 PUP D PUP 3.958 i 0o z,ol 6397 3399 HANGER D ABOVE HOOK HANGER 3.980 6407 3401 HANGER D INSIDE HOOK HANGER 3.980 6491 3417 PACKER iBl ZXP LINER TOP PACKER 4 950 ~snwunea 6813 3475 HANGER B ABOVE HOOK HANGER 3.980 g~a+-,z55a, 6823 _3477_, HANGER(Bl , INSIDE HOOK HANGER 3.980 o~awo,wc„sGl Other lu s, a ul etc _ A-SAND LINER DETAIL _ T __ De h TVD T e Descri lion ID 6931 3498 PACKER A HRD ZXP LINER TOP PACKER 5.500 6950 3501 NIPPLE A RS PACKOFF SEAL NIPPLE 4.870 6953 3502 HANGER A FLEXLOCK LINER HANGER 5.510 6963 3504 SBE A 190-47 CASING SEAL BORE EXTENSION 4.750 "`""" f 6982 3507 BUSHING (A) CROSSOVER BUSHING 3.930 _ - -_ -_ _ - -- General Notes eseaesea seE __ __ __ - - (~ t , Date Note wezea) -><.:-<.-<: - 7/1/2006 MULTI-LATERAL WELL: 1J-170 (A-SAND), 1J-170L1 (B-SAND), 1J-170L2 (D-SAND) TREE: VETCO GRAY / HORZ 14 1/8" 5M -TREE CAP CONNECTION: 9.5" OTIS ~ ~ ~ ~~ Perf (789E-7980) ~...:; .; Perf (B2B1J000) ~.... :.4.~:;.;'. :~:::~:~Y:~ Perf (92595732) .. Perf (10030-1059G) -: ~... _ . ~::.:.': i~ Per((t0B90.11354) ' ~.~", :>>~.. Pem(„e5zrzaa~ " Perf (12,75,2435) ~ ~ • __ i ao~-ova ~--, -~~~ Mv'C:iA3~ICAL INTEGRITY R :PORT - - ~ 6 _ , ~. _ _ BUD u :_: : - -~ - :-_G n..:.~~~ ~~ . Cement Volumes :~_ Amt. Liner Csg ~-l~oC7s ~ DV ~~ C~,t JoI to cover oer=s k~®.~~~~ Co`~1~~ ~ CiS~b`s~~~CoSi~> - ='eoretical TOC C.. (`~ `~`S ~"'~a~ ~~,~5~~ ~~c.cye~c~cc~vr~cacF-~,3~~f - LL DAT ~_ TD : .?~.. 'rVD ; ?ETD : ?•ID TVD C a s i~ g : ~~~~' Shoe : '~Ss~'~MD ~~5~ TVD ~ DV : ~ ~- ?~ ~ .d.-T~`Di ..:,er : Shoe: '~ T`TD ; ~'CP . t•~D ~'iD ~~ :~ o' _' e ~1)Z____P acicer ~'_-~ ole S~ce _ end C i=..r~?~ =C~.?, S.NTEGRTTY - PART # I rn~:ulus Press Test: _? Cocmaents : _TVD ; Set e t \^ S~c,,\ ~oc~ Perfs to ,^~~ ,. ~ ! `a ~c,,~c-~`~ 15 min ~0 min i '.~-CHPNICrs, INTEGRITY - PART # Z ~ ~~5~1~~`5 N ~~-, r' ~ f s J ~ ~ ~ d ~ OPER ~ FIELD C~ ~ .. ~~~ ~~ r~LL NUMBER ~.~ `- ~~~ ~~~~-.~- _ `~~ Cement Bond Log (Yes or No) ~ In AOGCC File C9L Evaluation, cone aoove perfs ~~,~~ ~~z-~~~~ ~J2`~ Production Log: Type ~ValL'atlon CONGLJS?Oi~S : ~ . Part 11 . - ?art #2: ~~ ~ 5 4-~ f~'rn ~13-~ ' o (~ WELL LOG TRANSMITTAL • To: State of Alaska July 19, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-170, PB1, PB2, Ll & L2, AK-MW-4406587 1 LDWG formatted CD Rom with verification listing(s). API#: 50-029-33100-00, 70, 71, 60, 61. ~v~-U~~ -a,33lp°-00 .~actit e o ~t e ~ ~•~- c~. o'~ _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ©©Anchorage,t`Alaska 99518 f~i~~l Ot ~~ Dat~U G 2 2 2006 Ala~tca Oil & Gas Ccmns. ca~mmis~ Mdmra9e Signed: C~~ -ova , ~~~~~_~ ~> , ~x;~t~ -~c y -~ ~ ~Ua_3 • 07-Aug-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-170 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,859.80' MD Window /Kickoff Survey: 7,940.00' MD (if applicable) Projected Survey: 11,916.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 i ned date S g Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) c: • 07-Aug-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-170 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 9,281.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. / Anchorage, AK 99518 ~ ~ _ /J / Date /~ 1N..~w J`1~h6 fe Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 07-Aug-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-170 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,226.90' MD Window /Kickoff Survey: 11,280.00' MD (if applicable) Projected Survey: 12,479.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) oZ~C9- '~~ z. • ConocoPhillips August 2, 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 ! ~~~~~,~ ~~ ~, p 3 2006 ,Alaska Oil & Cans Cons. G~m~`-ssi~tt Ancharege Subject: Well Completion Reports for 1 J-170, 1 J-170L1 and 1 J-170L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-170, 1J-170L1, 1J-170L2. If you have any questions regarding this matter, please contact me at 265-6830 or David Nugent at 265-6862. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~.EC~~v~ ^s;.~~ €~ 3 2006 WELL COMPLETION OR RECOMPLETION REPOIZTi~CI+-I~~S®~ Commission 1a. Well Status: Oil ^ - Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _XX Pre-Produced Injector ~ tb. Well Class: fIC Of8g8 Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: June 28, 2006 12. Permit to Drill Number: 206-062 / - 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 26, 2006 13. API Number: 50-029-23310-00 ' 4a. Location of Well (Governmental Section): Surface: 1802' FSL, 2489' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: June 9, 2006 14. Well Name and Number: 1J-170 At Top Productive Horizon: 1914' FNL, 616' FEL, Sec. 34, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Fieid Total Depth: 2557' FNL, 586' FEL, Sec. 27, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 12468' MD / 3701' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558722 ~ y- 5945614 Zone- 4 10. Total Depth (MD + TVD): 12479' MD ! 3702' TVD - 16. Property Designation: ADL 25660, 25661 TPI: x- 555302 y- 5947151 Zone- 4 Total Depth: x- 555291 ~ - 5951788 Zone- 4 11. Depth where SSSV set: nipple @ 509' 17. Land Use Permit: ALK 470 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 4574' 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" x 34" 62.6# H-40 28' 108' 28' 108' 42" 395 sx AS 1 10.75" 45.5# L-80 28' 3041' 28' 2146' 13.5" 560 sx AS Lite, 180 sx DeepCRETE 7-5/8" 29.7# L-80 28' 7894' 28' 3649' 9-7/8" 460 sx DeepCRETE 4.5" 11.6# L-80 6984' 12470' 3506' 3701' 6.75" slotted liner 23. Perforations 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" 6383' slotted liner from 7896' to 7980', 8281'-9000', 9258'-9732', 10030'-10589', 10890'-11354', 11657'-12003', 12175'-12434' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production July 18, 2006 Method of Operation (Flowing, gas lift, etc.) Pre-produced gas lift oil -shares production with 1 J-170L1 and 1 J-170L2 Date of Test 7/20/2006 Hours Tested 14 hours Production for Test Period --> OIL-BBL 1521 GAS-MCF 615 WATER-BBL 0 CHOKE SIZE 5 Bean GAS-OIL RA7lo 438 Flow Tubing Not available Casing Pressure 1360 Calculated 24-Hour Rate -> OIL-BBL 2535 GAS-MCF 1111 WATER-BBL 1 OIL GRAVITY -API (corr) not available 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". n~ S Di"~ p~G 1 ~ 2~~6 I}4Tr 'rte NONE VfRj ED Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL ~ ~$^qo i~~ ~ ~~~~ 2a. 2s. 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-170 Top West Sak 6410' 3401' West Sak A2 7829' 3645' West Sak A2 9200' 3652' West Sak A2 10740' 3647' N/A 1J-170P61 TD 9281' 3634' 1 J-170PB2 TD 11916' 3667' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 265-6862 Printed Name / and Thomas Title: Greater Kuoaruk Area Drillino Team Leader ~j~ Signature ~ ~ Phone Date /~ _ _ /~ ~/~~ Prepared by Sharon Allsup-Drake /TVJVa 7! INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet 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 C©noctiPhiiiips Time Log Summary WeJhiew tNeb RePDr#in9 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 05/25/2006 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Move rig to 1J-170. 05/26/2006 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Cont. to move rig from 1J-184 to 1J-170, Lay mat boards, spot pits, um s, motor & broiler com lexes. 03:00 03:30 0.50 0 0 MIRU MOVE PSIT P Spot rock washer 03:30 04:30 1.00 0 0 MIRU MOVE PSIT P Spot pipe sheds 04:30 09:00 4.50 0 0 MIRU MOVE OTHR P Work on rig pre-acceptance checklist. Install service lines, prepare pits to take on water. Assemble mud pump lines, assemble skate, level pipe shed. Berm rock washer. ACCEPT RIG @ 08:00 hrs. 09:00 12:00 3.00 0 0 SURFA DRILL PULD P PJSM: P/U 5" DP from shed and rack back in derrick. total of 78 'oints. 12:00 13:00 1.00 0 0 SURFA DRILL PULD P Cont to P/U DP and 6 stands of HWDP with 'ars and rack back. 13:00 13:30 0.50 0 0 SURFA WELCT BOPS P Perform diverter test. AOGCC Jeff Jones waived witnessin at 09:30 hrs. 13:30 14:30 1.00 0 0 SURFA DRILL PULD P Clean rig floor. P/U BHA from beaver slide. 14:30 15:30 1.00 0 0 SURFA DRILL PULD P Make up monels, bit and stablizer. 15:30 16:00 0.50 0 0 SURFA DRILL CIRC P Flood mudlines and conductor. 16:00 17:30 1.50 0 0 SURFA DRILL RURD P PJSM. Rig up gyro. 17:30 20:30 3.00 108 222 SURFA DRILL DRLG P Make up Bit #1 & Mud Motor, Spud well @ 17:30 hrs, Drill f/ 108' to 222' with 2 std's HWDP. 525 gpm, 550 psi, 60 r m, 0 for ue, 8K on bit. 20:30 23:00 2.50 222 222 SURFA DRILL TRIP P POOH, Change Motor bend to 1.83, P/U MWD and RIH to bottom. 23:00 00:00 1.00 222 254 SURFA DRILL DRLG P Drill from 222' to 254' @ 500 gpm, 900 psi, 40 rpm, 0 torque, 60 ROP, 8K on bit. 05/27/2006 00:00 12:00 12.00 254 966 SURFA DRILL DRLG P Drilled 13.5" hole from 254' to 966' MD. ART=4.15, AST=2.18, ADT=6.33 PU=77K, S0=76K, ROT=79K, TOon=3, TOoff=1 Jar hours=8.38 hrs, Max Gaa=+47 btu Byro depths: 253, 347, 440, 530, 621, 713, 816 .~~® _ ~'acfe 1 of 27 Time Logs Date From To Dur th E Depth. Phase Code Subcode T OM 05/27/2006 12:00 22:30 10.50 966 2,110 SURFA DRILL DRLG P Drilled 13.5" hole from 966' to 2110' MD, 1771 TVD 570 gpm, 1550 psi on btm, 1400 psi off btm, 6K TQ with pumps on PU=93K, S0=76K, ROT=89K with pumps on Jar hours=16.25 22:30 22:45 0.25 2,110 2,110 SURFA DRILL CIRC P Circ to clear BHA 22:45 00:00 1.25 2,110 1,835 SURFA DRILL REAM P Monitor well: Static. BROOH from 2110 to 1835 @ 700 gpm, 2000 psi, 45 rom, 4-5 TQ 05/28/2006 00:00 01:45 1.75 1,835 723 SURFA DRILL REAM P Cont to BROOH from 1835' MD to 732' MD. ROT at 40 rpm, 168 spm, 1900 si. 01:45 03:00 1.25 723 0 SURFA DRILL TRIP P POOH on elevators to surface. 03:00 03:30 0.50 0 0 SURFA DRILL OTHR P Drain motor, grade bit, turn motor to 1.15 de .Orient to MWD. 03:30 05:00 1.50 0 2,110 SURFA DRILL TRIP P RIH to 2020' wash and ream to 2110' MD at 520 gpm, 123 spm, ROT 10 r m, TO=3K. 05:00 12:00 7.00 2,110 2,759 SURFA DRILL DRLG P Drilled from 2110' to 2759' MD, 2031' TVD. ART=2.48, AST=1.52, ADT=4.0 PU=100K, S0=72K, TQon=8K, TQoff=4-6K M~c-Gas~~t732 $TU ~ 2642' MD, 1982' TVD. Jar hrs=20.25 12:00 14:45 2.75 2,759 3,050 SURFA DRILL DRLG P Drilled from 2759' to 3050' MD, 2149' TVD. ART=0.4, AST=0.67 ADT=1.07 PU=100K, S0=72K, TQon=8K, TQoff=5K Maus Gas~7 BTIJ Jar hrs=22.22 14:45 15:15 0.50 3,050 3,050 SURFA DRILL CIRC P Circ and condition mud. 15:15 18:00 2.75 3,050 1,186 SURFA DRILL REAM P Monitor well and BROOH from 3050' MD to 1186' MD at 700 gpm, 40 fpm, 2000 si, 100 r m, 5-8K. 18:00 19:30 1.50 1,186 163 SURFA DRILL TRIP P Pull last 4 stds of DP on elevators, LD ghost reamer and 3 stds HWDP. Rack back last 3 stands of HWDP & 'ars. 19:30 21:00 1.50 163 0 SURFA DRILL PULD P LD collars, MWD, motor and bit. 21:00 23:30 2.50 0 0 SURFA CASIN( RURD P Clear and clean rig floor. RU to run 10 3/4", 45.5#, L-80 BTC casin . 23:30 00:00 0.50 0 0 SURFA CASIN( RNCS P Dummy run landing joint. 05/29/2006 00:00 05:15 5.25 0 3,041 SURFA CASIN( RNCS P PJSM, Pick up 10-3/4" Shoe, 2 jts 10-3/4", 45.5#, L-80, BTC casing, Float collar and check floats- OK, Run 10-3l4" Casing to 3007' (Pumped down f/ 1707' to 1825'), Make up hanger and land casin 3041. 05:15 06:15 1.00 3,041 3,041 SURFA CASIN( CIRC P Circ btm's up at rate of 6 bpm @ 350 si. _ -ve® ~e f ~ j e ~ ®. ~._ ~ Time Logs -~ II Date From To Dur b~A th E. De th Phase Code Subcode T OM 05/29/2006 06:15 06:45 0.50 3,041 3,041 SURFA CEMEI~ RURD P Lay down Franks fill up tool, Make up Dowell cement head. 06:45 08:30 1.75 3,041 3,041 SURFA CEMEf~ CIRC P Continue to Circ. & Cond. mud for cement at rate of 7.0 bpm @ 4000 psi, Reciprocate: pi{~:10'-Mud prior to circ.= Wt. 9.4 ppg, Vis 278, PV 35, YP 58, Mud after= Wt. 9.1 ppg, Vis 44, PV 16, YP 5, Held PJSM with all hands and Dowell. 08:30 11:15 2.75 3,041 3,041 SURFA CEMEt~ CIRC P Turned over to Dowell and cemented 10 3/4" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, p 462.4 bttls; sxs) ofJead cement at 10.7 ppg and 4.63 yield with additives, ave 7.0 bpm at 200 psi, followed with 7g.5 btu (189 stcs) e#: rate tail cn-t a# 12.0 ppg and 2.47 yield with add., ave 6.9 bpm at 435 psi, reciprocated csg 10' arui had fuN-returns,. shut down and dropped top plug and Dowell pumped 20 bbls fresh water then turned over to rig. Rig displaced cement with 261.0 bbls (2592 stks) of 9.1 ppg mud, displaced cmt at 7.0 bpm, initial circ pressure 600 psi, max pressure 900 psi, slowed rate to 3 bpm and bumped plug on calc displacement, pressured up to 1300 psi, held 5 min, checked floats and held, CIP @ 11:15 hrs, had full r!ati,irttis during job and had 120.0 19.7* ~g c~r-t back to surface, reciprocated cs~ unto 1.12.5.. bbls cmt arced shoe -then pipe became tight, st wt up 165K, do wt 86K, Landed casing with Shoe @ 3,041.12' and Float collar 2,954.08'. 11:15 12:00 0.75 0 0 SURFA CEME~ RURD P Check float equipment, R/D cement e ui ment. 12:00 13:00 1.00 0 0 SURFA CEMEI~ RURD P Cont to R/D cmt equipment, clear and clean ri floor. 13:00 17:00 4.00 0 0 SURFA WELC7 NUND P Flush stack & N/D diveter with Crain. 17:00 18:30 1.50 0 0 SURFA RIGMN SVRG P Change out saver sub. 18:30 20:00 1.50 0 0 SURFA WELCT NUND P N!U wellhead & test to 5000 psi for 10 min. NU BOPE. 20:00 21:30 1.50 0 0 SURFA WELCT BOPE P RU BOPE test equipment. ~.~ ~€Je 3 ~f ~7 t ..~.,......_._ _. ®e ~ ®_~® .~... .~.~..~.... Time Los Date From To Dur th E. De th Phase Code Subcode T QOM 05/29/2006 21:30 00:00 2.50 0 SURFA WELCT BOPE P Start BOPE test with top set #1, #12, #13, #14, M/Kill, 4" dart valve, 2nd test: 4" TIW, HCR kill, #9, #11, 3rd: test lower IBOP, #5, #8, #10.4th test Upper IBOP, #4, #6, #7. 5th test: 5" TIW, #2. 6th test HCR choke, 5" Dart, 7th test annular w/ 4" DP, mania) choke, all test 250 low, 3000 psi high. Jeff Jones waived witnessing 5128/06 12:30 hrs. 05/30/2006 00:00 02:15 2.25 0 0 SURFA WELCT BOPE P Cont to test BOPs to 250 psi low, 3000 psi high. Test top rams w/ 5" DP, blind rams, lower pipe rams w/ 7 5/8", annular w/ 7 5/8".Accumulator test=inital 3000 psi, close 1800 psi, 200 psi attained 42 sec, full pressure in 3 min 21 sec, 5 bottle nitrogen avera a 2250 si. 02:15 02:45 0.50 0 0 SURFA WELCT OTHR P Set wear ring bushing. 02:45 03:45 1.00 0 0 SURFA DRILL OTHR P PJSM. RU short bails, elevators, inspect top drive. C/O heads on iron rou h neck. 03:45 06:45 3.00 0 0 SURFA DRILL TRIP P PJSM. RIH with 4" DP and rack back in derrick. 78 'oints 26 stands . 06:45 09:45 3.00 0 0 SURFA DRILL TRIP P PJSM. RIH with 87 joints 4" DP and rack back in derrick. 09:45 10:30 0.75 0 0 SURFA DRILL PULD P Clear and clean rig floor. P/U BHA from Beaver slide. 10:30 12:00 1.50 0 26 SURFA DRILL PULD P M/U 9 7/8" BHA: bit, motor, C!O roughneck heads to 5" for picking up MWD. 12:00 13:30 1.50 26 1,000 SURFA DRILL PULD P M/U float sub, stabilizer, MWD, NMFC, 'ars, HWDP, GR. 13:30 14:30 1.00 1,000 2,951 SURFA DRILL TRIP P TIH and tag float collar at 2,951' MD. 14:30 15:30 1.00 2,951 2,951 SURFA DRILL CIRC P Circ and condition mud for casing test. 15:30 16:00 0.50 2,951 2,951 SURFA CASIN( DHEQ P T~sfcasingto ~ for 30 nos on chart. 16:00 17:15 1.25 2,951 3,070 SURFA DRILL REAM P Wash and ream to shoe at 3,041', drill out shoe track plus 20' of rat hole to 3,070' MD. 17:15 17:45 0.50 3,070 3,070 SURFA DRILL CIRC P Circ and condition mud and R/U for LOT. 17:45 18:30 0.75 3,070 3,070 SURFA DRILL LOT P Perform LOT on chart at 10 spm, 56 strokes, 5.6 bbls. at 3041' MD, 2,146' TVD w/ 600 psi, 9.0 ppg =:14.4-~ EMW 18:30 00:00 5.50 3,070 3,755 INTRM1 DRILL DRLG P Drill from 3,070' to 3,755' MD, 2,463' TVD AST=1.62, ART=1.14, ATD=1.67 hrs PU=112K, So=65K, ROT=82K, TQoff=5-7K Jar hrs=2.76 hrs ~ _. _ _s________.~. _~ ~'~~_ o_ , ~ ~.... Time Logs ~ Date From To Dur _ pth E. De th Phase Code Subc ,OM 05/31/2006 00:00 12:00 12.00 3,755 . 5,007 INTRM1 DRILL DRLG P Drill from 3,755' to 5007' MD, 2981' TVD AST=4.97, ART=,4.97 ATD= 7.24hrs PU= 128K, S0= 65K, ROT= 85K, TQoff= 7K, TQon= 8K Jar hrs =31.94 hrs 600 gpm, 2000 psi, W0B=5-30K, ROT=85 rpm Pumped sweep at 4586' with 15% increase in returns. 12:00 00:00 12.00 5,007 5,947 INTRM1 DRILL DRLG P Drill from 5,007' to 5,947' MD, 3,313' TVD AST=7.04, ART= 3.37, ATD= 10.41 hrs PU= 116K, S0= 79K, ROT= None to maintain directional work, TQon= 6K Jar hrs = 42.35 hrs ECD=10.04, Max Gas = 59 btu 500 gpm, 85 rpm, WO6=5-30K, 2250 psi Added 2% lubricants at 16:00, 5300' MD 06/01/2006 00:00 12:00 12.00 5,947 6,747 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 5,947' to 6,747' (800') 3,463' TVD, WOB 10-35K, RPM 85, 600 gpm @ 2100 psi, Up 117K, Dn 72K, Rot 87K, TQ 8K on/ 5-7K off, Ave ECD's 9.89 ppg, Maas gas 137 Units, Concretions 6,150' to 6,170', 6,510' to 6,530'. 12:00 00:00 12.00 6,747 7,814 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 6,747' to 7,814' (1,067') 3,643' TVD, ART= 7.25 hrs, AST= 2.42 hrs, ADT= 9.67 hrs, WOB 15-25K, RPM 85, 625 gpm @ 2675 psi, Up 121 K, Dn 71 K, Rot 87K, TQ 7K on/ 5-7K off, Ave ECD's 10.41 Maas ~s 88 Units.. 06/02/2006 00:00 02:00 2.00 7,814 7,900 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 7,814' to 7,900' (86') 3,650' TVD, ART= 1.05 hrs, AST= 0.62 hrs, ADT= 1.67 hrs, WOB 10-30K, RPM 90, 650 gpm @ 2400 psi, Up 121 K, Dn 71 K, Rot 87K, TQ 6-8K on/ 5-7K off, Ave ECD's 10.01 , Max as 89 t7nits. 02:00 03:15 1.25 7,900 7,900 INTRM1 DRILL CIRC P Pump Hi-vis Weighted sweep &Circ hole clean at rate of 600 gpm @ 2200 psi, 90 RPM - No increase in cuttings from swee . 03:15 09:45 6.50 7,900 3,040 INTRM1 DRILL REAM P Monitor well, Back Ream out of hole f/ 7,900' to 3,040' at rate of 40/45 ft/min. w/ 650 gpm @ 2350 psi & 90 RPM, TQ 6-7K. Hole in ve ood sha e. 09:45 10:30 0.75 3,040 3,040 INTRM1 DRILL CIRC P Pump Hi-vis weighted sweep &Circ hole clean with 3 Btm's u . 10:30 15:00 4.50 3,040 0 INTRM1 DRILL PULD P Pump dry job, POOH & Lay down all 5" drill pipe, HWDP, Jars, Down load MWD tools, La down BHA. - _ ~gL a~ r~f 7 ~_ Time t_o~_ Date From To Dur th E. De th Phase `Code Subcode T OM 06/02/2006 15:00 16:00 1.00 0 0 iNTRM1 DRILL PULD P Clean & clear rig floor of all drill tools. 16:00 17:30 1.50 0 INTRM1 CASIN( RURD P Rig to Run 7-5/8" casing. 17:30 00:00 6.50 0 4,360 INTRM1 CASIN( RNCS P Run 7-5/8" Shoe (1.51'), 2 jts 7-5/8", 29.7#, L-80, BTCM (87.36'), Float Collar (1.28'), 22 jts csg (937.91'), 1- Pup jt (6.18'), 1- Window jt. (43.04'), 8 jts csg (337.47'), 3- Pup jts (37.37'), 1- Window jt (42.15'), Continue running to a total of 100 jts to 4,360' at 23:59 hrs., Circ Btm's up at shoe @ 3,030' with no problems at rate of 6 bpm @ 350 si. 06/03/2006 00:00 02:45 2.75 4,360 7,894 INTRM1 CASIN( RNCS P Continue to run 7-5/8" casing f! 4,360' to 7,894' (Tagged Btm with extra joint #184 & la ed down same . 02:45 03:45 1.00 7,894 7,894 INTRM1 CEMEI~ PULD P RD Franks fill up tool and MU Dowell's cement head. 03:45 06:00 2.25 7,894 7,894 INTRM1 CEMEf~ CIRC P Circ and Cond mud for cementing, Circ at 6.5 bpm at 425 psi, Up 195K, Dn 80K, Initial MW out, 9.3+ ppg, 56 vis, PV 12, YP 23, Conditioned mud to final MW of 9.0 ppg, 39 vis, 7 PV and 12 YP, Held PJSM with Dowell, ASRC vac truck drivers and rig crew on cementin cs while circ hole. 06:00 08:30 2.50 7,894 7,894 INTRMI CEMEI~ CIRC T While priming up Dowell cement unit one of the engines had a fuel pump failure. Wait on another cement unit while continuing to circ & condition mud. ~ .~ _.~... ~. ,® ~.~... ~~ ~ ~f ~? Time Logs ~ ~ ~ `` Date From To Dur th E. De th Phase Code Subcode T OM ~ 06/03/2006 08:30 11:00 2.50 7,894 7,894 INTRM1 CEMEC` DISP P Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.6 bpm @ 185 psi, Pressure tested lines to 3,500 psi, Then pumped 65 add. bbls of CW 100 at rate of 4.5 bpm @ 190 psi, Dropped btm plug, Pumped 75 bbls of MudPush at 11.0 ppg at rate of 4.6 bpm @ 230 psi, Followed by 184o~<<bbls, (,4fi0 sxs - 25% a,~ ceatet~ of DeepCrete cmt at 12.5 ,pp{~, x.25 yield additives, ave 4.5 bpm at 205 psi, Reciprocated' pipe mil' with fufl cMcarns. Drop top plug and Dowell kicked top plug out with 5 bbls fresh water. Rig displaced cement with 9.0 ppg OBM, Bumped plug on calc displacement after pumping 353.2 bbls OBM (Total of 358.2 bbls) (96% pump eff.) ave 7 bpm while displacing cmt, Initial pressure 300 psi, Max pressure 1150 psi, Slowed pump rate to 3 bpm 750 psi) with 10 bbls left to pump and bumped plug to 1300 psi, ck floats and held. CIP at 11:00 hrs. 6/3!06. Reciproc~.ated pips art~1 87.3 bbls cmt was around shoe why hole began 9~n9 ing, landed csg with Shoe @ 7,894.00', Float Collar @ 7,803.85', Calc TOC @ 4,167', Had full returns thru out job. Well static after shut down. 11:00 12:00 1.00 0 0 INTRM1 CEMEI~ PULD P Rig down Dowell cement head, Vacuum out OBM from cut off stub. 12:00 12:30 0.50 0 INTRM1 CASIN( NUND P Nipple down well head and raise stack, Set casing slips w/ 155K on indicator - tention 75K. 12:30 16:30 4.00 0 0 INTRM1 CASIN( NUND P Cold cut 7-5/8" casing, Remove cut off, Install pack off, Nipple up well head & stack, Test pack off and flange break to 3800 psi f/ 10 min- OK, Install wear bushin . 16:30 18:00 1.50 0 INTRM1 DRILL PULD P Bring 4" Lo-Tad's to rig floor, Rig to pick up 4" drill pipe, Pick 21 joints 4" XT-39 HWDP. Note; Perform infectivity test on 7-5/8" x 10-3/4" annulaus with 9.0 ppg mud, 450 psi, 2149' TVD= 13U ppg E~A!_ Flush annulus with total of 141 bbls fresh water at rate of 2.0 bpm @ 760 si. ~~_ ~m ~ ~ ~~,~ ~~~ ~ ~t ~7 ~ .~ ... .~.~.~ Time Logs Date From To Dur >~ E. De th Phase Code Subcode T bM 06/03/2006 18:00 19:00 1.00 INTRMI DRILL PULD P Pick up 51 jts 4" XT-39 drill pipe from pipe shed. Note; Rig little red servixce and freeze protect 7-5/8" x 10-3/4" annulus with 85 bbls diesel at rate of 1.8 bpm @ 800 si. 19:00 21:00 2.00 INTRM1 DRILL PULD P POOH installing 4" Lo-Tad's and rack back 17 stands in derrick. 21:00 00:00 3.00 INTRMI DRILL PULD P Pick up 99 joints 4" XT-39 drill pipe with WWT Sliders installed from pipe shed. 06/04/2006 00:00 03:15 3.25 3,720 0 INTRMI DRILL PULD P POOH and stand back 33 stands 4" D. P. with Sliders and install 1-Lo Tad per stand, Stand back 7 stands 4" HWDP. 03:15 03:45 0.50 0 0 INTRM1 DRILL PULD P Clear & Clean rig floor. 03:45 07:00 3.25 0 0 INTRM1 DRILL PULD P Rig & Pick up 15 stands Hybrid Push Pipe (2-jts 4-3/4" Spiral DC's & 1-jt HWDP), POOH and stand back 15 stands Push Pi e. 07:00 10:45 3.75 0 360 INTRM1 DRILL PULD P PJSM, Pick up BHA #4 -6-3/4" Bit #3, 4-3/4" 5200 Geo Pilot, MWD tools, Stab's, Flex collars & HWDP, Break in Geo Pilot. 10:45 12:30 1.75 360 2,160 INTRM1 DRILL TRIP P Pick up 60 jts 4" Drill pipe from pipe shed. 12:30 15:00 2.50 2,160 7,803 INTRM1 DRILL TRIP P RIH w/ pipe from derrick to 7,790', Screw into top dive, Pump down and to float collar 7,803'- OK. 15:00 15:30 0.50 7,803 7,803 INTRM1 DRILL CIRC P Circ Btm's up for 7-5/8" Casing test. 15:30 16:45 1.25 7,803 7,803 INTRM1 RIGMN SVRG P Cut & Slip drilling line 86', Service top drive & Drawworks, Check saver sub. 16:45 17:45 1.00 7,803 7,803 INTRM1 DRILL DHEO P Rig & Test 7-5/8" Casing to 3000 psi for 30 min.- OK. 17:45 20:00 2.25 7,803 7,920 INTRM1 CEMEI~ DRLG P Drill out float collar @ 7,803', Cement & Shoe 7,894', 20:00 20:15 0.25 7,900 7,920 INTRM1 DRILL DDRL P Drill 20' new hole to 7920' MD / 3,651' TVD. 20:15 21:00 0.75 7,920 7,920 INTRM1 DRILL LOT P Rig & m LOT with 8.7 ppg mud, 3650' TVD, 1184 si = ~F9 ~. 21:00 00:00 3.00 7,920 8,270 PROD1 DRILL DDRL P Drill ahead with Sperry-Sun Geo Pilot f/ 7,920' to 8,270' MD / 3,668' TVD, ADT= 1.71 hrs., WOB 7-8K, RPM 110, 300 gpm @ 2650 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max as 62 units, Ave ECD's 10.2 06/05/2006 00:00 00:30 0.50 8,270 8,367 PROD1 DRILL DDRL P Drill w/ Geo Pilot f/ 8,270' to 8,367' MD (97'), ADT= .56 hrs., WOB 5-7K, RPM 120, 306 gpm @ 2600 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max gas 62 units, Ave ECD's 10.2 .~~ ., _~ ~~ ~~ ~ oaf 7 Time Lo s Date From To Dur 5. th E. Det~th Phase Code Subcod'e T OM 06/05/2006 00:30 02:30 2.00 8,367 8,367 PROD1 DRILL WOOR NP Circ at rate f/ Geologist to evaluate to s with Anchora e. 02:30 03:45 1.25 8,367 8,514 PROD1 DRILL DDRL P Drill w/ Geo Pilot f/ 8,367' to 8,514' MD (147'), ADT= .56 hrs., WOB 12-15K, RPM 100, 270 gpm @ 2250 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max gas 62 units, Ave ECD's 10.2 03:45 04:30 0.75 8,514 8,514 PROD1 DRILL REAM NP Evaluate for Geologist -Back ream f/ 8,514' to 8,365' for possible Sidetrack - Chan a of Ian & Return to Btm. 04:30 10:45 6.25 8,514 9,281 PROD1 DRILL DDRL P Drill w/ Geo Pilot f/ 8,514' to 92$' A+~3 / 3,634' TVD (767'), ADT= .4.53 hrs., WOB 8-12K, RPM 130, 313 gpm @ 2875 psi, Up 135K, Dn 52K, Rot 86K, Tq on 6.5K/7K off, Max 132 tanits, Ave ECD's 10.7 10:45 12:15 1.50 9,281 7,887 PROD1 STK TRIP NP Monitor well- OK, POOH on elevators to 7,887' for SideTrack. 12:15 13:00 0.75 7,887 7,940 PROD1 STK KOST NP Orient Geo Pilot & Trench f/ 7,887' to 7,940'. 13:00 16:30 3.50 7,940 7,990 PROD1 STK KOST NP Time drill f/ 7,840' to 7,990', ADT= 2.0 hrs w/ 100 RPM 300 m 2600 si. 16:30 00:00 7.50 7,990 8,657 PROD1 DRILL DDRL NP Drill w/ Geo Pilot f/ 7,990 to 8,657' MD / 3,652' TVD (3,652'), ADT= 6.18 hrs., WOB 5-12K, RPM 130, 313 gpm @ 2600 psi, Up 130K, Dn 65K, Rot 84K, Tq on 6K/6K off, M~#at ?44 tuiits, Ave ECD's 10.3 06/06/2006 00:00 05:30 5.50 8,657 9,206 PROD1 DRILL DDRL NP Drlg f/ 8657' to 9206'MD / 3650' TVD ADT= 5.34 hrs, PU wt 138k, SO wt 55k, Rot wt 85k, Troq on bttm 7k, off bttm 7.5k 05:30 06:00 0.50 9,206 9,206 PROD1 DRILL CIRC NP Circu -Geologist evaluate logs 06:00 12:00 6.00 9,206 9,875 PROD1 DRILL DDRL P Drlg (19206' to 9875' MD ADT 3.48 - Pumped WUHiVis sweep @ 9527' MD with NO % increase in cuttings. Up wt and Dn wt showing large increases on T&G model. Rig engineer checking all data to make sure it is correct. PU wt 150k, SO wt Ok, Torq off bttm 7k, on bttm 7k, Mt9x Gay 'k02, ECDs 10.88, Jar hrs total 99.65 12:00 13:30 1.50 9,875 10,159 PROD1 DRILL DDRL P Drlg f/ 9875' to 10,159' MD / 3646' TVD - PU wt 165k, SO wt Ok, Rot wt 84k, Torq on bttm 7k, off bttm 7k -ADT 1.15 hrs 13:30 13:45 0.25 10,159 10,159 PROD1 DRILL CIRC T Circu - MWD computer reboot- Locked u 13:45 15:30 1.75 10,159 10,397 PROD1 DRILL DDRL P Drlg f/ 10,159' to 10,397' MD ! 3646' TVD. ECDs Model still showed T&D with large increases on Up wt and NO do wt. Decission was made to make wiper trip to the shoe to evaluate hole conditions. P~~ 9 cif 27~ Time Logs ~ _ Date From To Dur _ „ th E. Depth Phase Code Subcode T _ O_M 06/06/2006 15:30 15:45 0.25 10,397 10,397 PROD1 DRILL CIRC P Circu- Pump sweep & condition hole for wi er tri -Zero toolface on GeoPilot 15:45 19:00 3.25 10,397 7,894 PROD1 DRILL REAM P Wiper Trip - BROOH f/ 10,397' MD to 7894' MD(7.625" shoe) PR 310 GPM, RPMs 85 - No roblems seen. 19:00 20:15 1.25 7,894 7,894 PROD1 DRILL CIRC P Pump 30 bbl WbHiVis sweep -Rot & Recip string - PR 310 gpm, RPMs 85- Sweep to surface saw 5% increase in cutting. Up wt 170k, Dn wt 70k in casin . 20:15 20:45 0.50 7,894 7,940 PROD1 DRILL TRIP P TIH -Pump down 3 stds -orient tool thru kick off area @ 7940' -Entered new well bore without an roblems. 20:45 21:45 1.00 7,940 10,111 PROD1 DRILL TRIP P TIH on elevators to 10,111' 21:45 22:15 0.50 10,111 10,396 PROD1 DRILL REAM P Wash & Ream 10,111' to 10,396' MD - PR 310 m, RPMs 80, PP 2800 si 22:15 00:00 1.75 10,397 10,558 PROD1 DRILL DDRL P Top Drive up @ Std #106, Orient Geo Pilot, Drlg f/ 10,397' to 10,558' MD / 3649' TVD - PR 310 gpm, PP 3000 psi, RPMs 125, WOB 6-8k, Torq 7k on bttm. ADT= .76 06/07/2006 00:00 00:30 0.50 10,558 10,558 PROD1 DRILL CIRC T Made several attempts to get GeoPilot to respond to signal - No responce - Monitorwell -Static 00:30 02:00 1.50 10,558 7,870 PROD1 DRILL TRIP T POOH on elevators 10,558' to 7870' MD with no roblems 02:00 02:30 0.50 7,870 7,780 PROD1 DRILL OWFF T Observe well for flow -Pump dry job 02:30 05:00 2.50 7,780 360 PROD1 DRILL TRIP T POOH on elevators 7,870' to 360'. Displ for trip =actual 66 bbls, calculated 60.2 05:00 05:30 0.50 360 90 PROD1 DRILL TRIP T Stand back 2 stds HWDP w/Jars and 1 std NMFDCs 05:30 06:00 0.50 90 90 PROD1 DRILL SRVY T Down Load MWD 06:00 07:00 1.00 0 0 PROD1 DRILL PULD T UD BHA #4 - FS, Stab, MWD, Smart Sub, DM, NM Geo flex, Geopilot & bit.. Bit looks good -grade 1 -1 will run back. 07:00 07:45 0.75 0 90 PROD1 DRILL PULD T PU & MU BHA #5 -GeoPilot, Bit, NM Geo Flex, DM, Smart Stb & MWD 07:45 08:30 0.75 90 90 PROD1 DRILL SRVY T Up Load MWD 08:30 09:15 0.75 90 360 PROD1 DRILL PULD T Con't MU BHA#5 - PU FS, Stab, 1 std NMFDCs, 2 stds HWDP w/ jars - Break in GeoPilot bearings -Shallow test MWD 80SPM = 1200 psi -good ulse. 09:15 12:00 2.75 360 7,403 PROD1 DRILL TRIP T TIH on elevators f/ 360' to 7,403' MD , U wt 110k, Dn wt 70k 12:00 13:30 1.50 7,403 9,020 PROD1 DRILL TRIP T TIH on elevators f / 7,403' to 9,020' Floor crew doing visual check on WWT SS and Lo Tads on trip in) observed no problems. @ 9020' encountered tight hole, No SO wt. ® ®. ~ ~ ~. ~ t ~~: 1~ of ? ~ Time Logs ~- Date From To Dur th E. De th Phase Code Subcode T QOM 06/07/2006 13:30 17:00 3.50 9,020 10,558 PROD1 DRILL REAM T Wash & Ream f/ 9020' to 10,558' MD . PR 300 gpm, 50 RPMs, Torq on bttm 7-8k, PP 2700 si, 17:00 17:15 0.25 10,558 10,558 PROD1 DRILL SRVY T Orient and Set Tool deflection 17:15 00:00 6.75 10,558 11,168 PROD1 DRILL DDRL P Drlg f/ 10,558' to 11,168' MD / 3660' TVD, PR 310 gpm, RPMs 120, PP 3000 psi, WOB 7-9k, Stage up ROP timed out to clean hole from 100 - 125 fph PU wt 160 k/, SO wt 0 k, Rot wt 84 k Torq on bttm 6 k, off bttm 7 k Max gas>30 units, ECDs 10.92ppg Total jar hrs 107.34 @ Midnight - 99 WWT SS & 50 Lo Tads in hole. 06/08/2006 00:00 08:00 8.00 11,168 11,915 PROD1 DRILL DDRL P Drlg 6 3/4" hole w/ Geo Pilot f/ 11,168' - 11,915' MD / 3667' TVD, ADT 5.93 hrs, PR 310 gpm, PP 3100, RPMs 130, WOB 5-14 k, """ 'st reported they had de of zone""" 08:00 09:00 1.00 11,915 11,267 PROD1 DRILL REAM T BROOH for Sici® Track t/ 11,267' MD , FR 300 m, RPMs 110, Tor 7 k 09:00 10:00 1.00 11,267 11,280 PROD1 DRILL KOST T Set Up for side track, Trench f/ 11,267' to 11,280' MD / 3656' TVD, PP 2900 si, RPMs, Tor 7 k 10:00 12:00 2.00 11,280 11,284 PROD1 DRILL KOST T Time drlg for sidetrack. f/ 11,280' to 11,284' MD ADT 1.37 hrs # of T&D tools in hole, 99 WWT SS and 50 4" Lo Tads @11,915'MDPUwt154k,SOwtOk, Rot wt 85k, Tor on bttm 7 k, off bttm 8.5 k 12:00 14:30 2.50 11,284 11,304 PROD1 DRILL KOST T Con't Time drlg f/ 11,284' to 11,304' *"* Departure Point 11, 285' MD / 3656.69' TVD 14:30 16:00 1.50 11,304 11,358 PROD1 DRILL DDRL T Drlg 6 3/4" hole w/ Geo Pilot f/ 11,304' MD to 11,358' MD. Pump 35 Bbl wt/hi-vis sweep while drilling ahead @ 11,358' MD. 250 gpm, 2750 psi, 120 rpm, and 80-90 fph until sweep past MWD tool (1500 stks), then increase rate to 310 gpm, 3000 psi, 125-135 fph, 130 rpm ... sweep brought back 20% increase in cuttin s. 16:00 21:45 5.75 11,358 11,915 PROD1 DRILL DDRL T Drlg 6-3/4" hole w/ Geo-Pilot f/ 11,358' MD to 11915' MD. SPR @ 12,006' MD, 3673' TVD, MW = 8.7+, MP#1 @ 25 spm = 660 psi, @ 35 spm = 830 psi, MP#2 @ 25 spm = 660 psi, @ 35 s m = 830 si ~_ e .~~ _ ~a®_ ~_ ~ ~ __,_....~... ___ __ ~ ~'~~~ ~t' cai ~~' Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 06/08/2006 21:45 00:00 2.25 11,915 12,006 PROD1 DRILL DDRL P Drlg 6-3/4" hole w/ Geo-Pilot f/ 11,915' MD to 12,006' MD (3,673' ND). ADT = 8.81, PU = 165, SO = 0, Rot wt = 84, TQ On = 8k, TQ Off = 9k, Max Gas = 110 units, ECD = 11.34, Jar Hrs = 123.45. #/Lo-TADs in Hole = 50, Su er-Sliders = 99 06/09/2006 00:00 05:00 5.00 12,006 12,479 PROD1 DRILL DDRL P Drlg 6 3/4" hole w/ GeoPliot f/ 12,006' to 12,479' MD / 3703' ND,= "A" Lat TD - ADT 4.19 hrs PU wt 170k, SO wt 0 k, Rot wt 90k, Torq 8 k, MAx gas 69 units, ECDs 11.42 ppg, Jar Hrs 127.64 PR 310 gpm, PP 3200 psi, RPMs 120-130 05:00 06:15 1.25 12,479 12,479 PROD1 DRILL CIRC P Pump Wt/Hi Vis sweep on last stand down -Circu BU 06:15 06:30 0.25 12,479 12,479 PROD1 DRILL OWFF P Record SPR -Observe Well- Static 06:30 12:00 5.50 12,479 8,757 PROD1 DRILL TRIP P BROOH f/ 12,479' to 8757' MD. FR 310 gpm, RPMs 120. Pull slow and steady +/- 45 fpm. No problems encounted. 12:00 13:00 1.00 8,757 7,790 PROD1 DRILL TRIP P PJSM- Con't BROOH f/ 8757' to 7790' MD. PR 310 gpm, RPMs 120. Slowed to 100 RPMs at shoe. 13:00 14:00 1.00 7,790 7,790 PROD1 DRILL CIRC P Pump Wt/Hi Vis sweep -Circu and recip csg until clean, PR 310 gpm, RPMs 100, Recip 90'- 0% excess cuttin on BU 14:00 18:00 4.00 7,790 12,479 PROD1 DRILL TRIP P RIH- Fill DP every 2000' -Tight @ 10,720' -Break Circu and PD f/ 10,691' to 10,788'. Con't RIH to Bttm with no problems on elevators. Wash & Ream 12,372' to 12,479' - PU wt 170k, SO wt 45k, Rot wt 85k 18:00 20:00 2.00 12,479 12,479 PROD1 DRILL CIRC P Pump sweep -Circu & Condition hole PR 310 gpm, RPMs 120, Recip DP 90' - Circu until clean at shakers. 20:00 21:00 1.00 12,479 12,479 PROD1 DRILL CIRC P Change out to SFOBM -Displace to SFOBM from 12,479' to 6600' (200' above B lat window) -Last 20 bbls dis lacement is d 'ob. 21:00 00:00 3.00 12,479 8,885 PROD1 DRILL TRIP P POOH - SLM - Ck and Servive WWT SS. Sliders were moved do one space for wear protection to pipe. Had to re lace 1 element sleeve. 06/10/2006 00:00 01:30 1.50 9,144 7,887 PROD1 DRILL TRIP P Con't TOH f/ 9144' MD to 7887' MD - WWT SS were inspected and move down 1 position to minimize pipe ex osure to wear. 01:30 01:45 0.25 7,887 7,887 PROD1 DRILL SFTY P Observe well at 7-5/8" csg shoe - STATIC .. _ ~_ ~ - .~ ~e 4 Time Logs ~ _ Date From To Dur I~ thth E. De th Phase Code Subcode T _ ~M 06/10/2006 01:45 04:15 2.50 7,887 6,243 PROD1 DRILL TRIP P Con't TOH f/ 7887' to 6243' MD WWT SS were inspected and moved down 1 position to minimize pipe exposure to wear. -Replaced 1 bad sleeve due to wear. -Inspected total 90 WWT SS - All Lo Tads appeared to be in good shape -minimal wear. 50 total in strin . 04:15 06:15 2.00 6,243 360 PROD1 DRILL TRIP P Con't TOH f/ 6243' to 360' 06:15 06:45 0.50 360 360 PROD1 DRILL TRIP P BHA #5 -Stand back 2 std HWDP w/ 'ars and 1 std of NMFDCs 06:45 07:30 0.75 360 90 PROD1 DRILL SRVY P Down Load MWD - ** Note*" Due to comm problem tool had to be laid down before data could be down loaded. After tool was LD in the shed the data was exstracted "OK" 07:30 08:15 0.75 90 0 PROD1 DRILL PULD P Con't LD BHA #5 - LD stab,NM Flt sub, TM HOC, PWD, SP 4 w/ Gm & Rec, Smart stab, DM HOC, NM sht DC, Geo- ilot 5200 Sr# 4 & bit 08:15 08:30 0.25 0 0 PROD1 DRILL PULD P Clear all tools from rig floor -Clean rig floor 08:30 09:15 0.75 0 0 PROD1 RIGMN SVRG P PJSM -Slip & Cut drill line (85.5' cut) 09:15 10:15 1.00 0 0 COMPZ CASIN( RURD P PJSM - RU to run 4.5" slotted liner 10:15 12:00 1.75 0 756 COMPZ CASIN( RUNL P Run 4.5" slotted liner in "A" lat per detail -Run 18 'ts. 12:00 14:30 2.50 756 5,550 COMPZ CASIN( RUNL P PJSM - Con't Run 4.5" slotted liner in "A" lat. per detail. Total jts ran 127, 68 jts slotted and 59 jts blank + 1 blank shoe 'oint. 14:30 16:00 1.50 5,550 5,590 COMPZ CASIN( PUTB P PU Liner Hanger Assy - 7.625' X 5.5" HRD ZXP LTP, RS packoff seal nipple, Flex Lock LH, 190-47 CSB Ext, XO bushing w/ 3.93" ID -See running detail for full data -Install PAL mix - RD Csg Tools & clear off all un-needed equip from rig floor. Up wt 77k, SO 60k, Rot wt 67k, Torq 2k 16:00 17:30 1.50 5,590 7,871 COMPZ CASIN( RUNL P TIH w/ Liner on DP to shoe -Fill DP @ 7871' - Up wt 100k, SO wt 65k, Rot wt 78k, Tor 3k 17:30 22:00 4.50 7,871 12,470 COMPZ CASIN( RUNL P TIH f/ 7871' to 12,470' -Had to rotate thru several spots, @ 10,045', 10,330', 10,830' 11,080', 11,180', 11,595', 11,614'. 50 RPMs, Max torq seen 8 k. @ 12,470 = UP wt 180k, SO wt 70k - Brk circu. 22:00 22:30 0.50 12,470 12,470 COMPZ CASIN( CIRC P Drop & Circu setting ball to seat. - PR 3 bpm, 550 psi, Slow to 2 bpm for last 500 stks. Ball on seat m ~.. ~ ~.~,.-.,m.dW~,...~.~~ ~ ~ag~ ~? ~~ 2~ Time Lo~c s Date From To Dur th E. De th Phase Code Subcode T QM 06/10/2006 22:30 00:00 1.50 12,470 12,470 COMPZ CASIN( RUNL P Ball on seat -Pressure up to 1800 psi, Set liner hanger, apply do wt 20k, Increase pressure to 3000 psi to set packer, Pressure test packer do back side to 1000 psi on chart and hold for 10 min. "OK" Pick up and expose dog sub. Apply do wt w/dog sub to confirm liner set. "OK" Top of Liner @ 6931' MD, 06/11/2006 00:00 02:00 2.00 6,990 0 COMPZ CASIN( RUNL P TOH f/ 6990' with liner setting tool - Hole fill Calcu 55 bbls, Actual 61 bbls - Settin tool all com lete. Worked well 02:00 02:45 0.75 0 0 COMPZ CASIN( RUNL P Service Brk & L/D Baker Liner running tool 02:45 03:15 0.50 0 0 COMPZ RIGMN SVRG P Service Rig and Top Drive 03:15 03:45 0.50 0 0 COMPZ CASIN( RURD P Clear all tools from rig floor and clean u work area. 03:45 05:30 1.75 0 0 COMPZ EVALVI RURD P RU Schlumberger wire line to run CBL on 7.625" interm. 05:30 06:30 1.00 0 0 COMPZ EVALV~ RURD P PU wireline tools from unit to rig floor. RU sheave 06:30 07:30 1.00 0 0 COMPZ EVALV~ PULD T Trouble shoot wireline tractor. 07:30 12:00 4.50 0 0 COMPZ EVALN~ ELOG P Start in hole with USIT CBL logging tools. Ran to 5940' (76.4') without tractor. Tractor in f/ 5940' to 6915' MD- Lo u 1400 fUhr noon 4400' 12:00 13:30 1.50 0 0 COMPZ EVALVI~ ELOG P Con't logging up from 4400' to 2950'. Cmt appears good up to 3700'-. And diminishes from there to 3050' MD. 13:30 14:30 1.00 0 0 COMPZ EVALV~ PULD P LD wireline tools - RD Logging unit and tools 14:30 16:30 2.00 0 0 PROD2 DRILL PULD P PJSM - PU Mill and Whipstock assy. Usin 35k shear bolt. 16:30 17:00 0.50 0 0 PROD2 DRILL SRVY P PU Super Slim MWD and orient to WS. PU Bum er sub 17:00 18:00 1.00 0 0 PROD2 DRILL SRVY P Up Load program MWD 18:00 18:30 0.50 0 210 PROD2 DRILL TRIP P TIH w/ 2 stds Hybrid push pipe & shallow pulse test @ 393' MD, 6 bpm, 850 si "OK" 18:30 19:00 0.50 210 1,651 PROD2 DRILL TRIP P Con't TIH with whipstock assy to 1651' 19:00 19:30 0.50 1,651 1,651 PROD2 DRILL PULD NP CO 2 joints of 4" DP with galled threads 19:30 21:30 2.00 1,651 5,430 PROD2 DRILL TRIP P Con't TIH 5430' (fill pipe @ 3394' & break circu 5430' 21:30 22:15 0.75 5,430 5,520 PROD2 DRILL SRVY P MADD pass f/ 5430' to 5520' for tie in of K-13 logs assuring proper depth. Orient TF to 10-15"L) during this rocess 22:15 23:00 0.75 5,520 6,894 PROD2 DRILL TRIP P Con't TIH to 6863' PU single to space Kelly to mill window. Up wt 144k, SO wt 87k ~'~~ 3~ cf ;~? Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 06/11/2006 23:00 00:00 1.00 6,894 6,931 PROD2 DRILL MILL P Orient & Set Whipstock @ 7" Left - Good indication of positive shear. No ~l _, ~~ 1 _~ ~ l1 ~1~~ 4 ~ Go tagged up on depth @6931' MD After shear window starter mill @ 6826' TOW 06/12/2006 00:00 10:00 10.00 6,826 6,855 PROD2 DRILL MILL P Mill window for "B" sand lat. TOW 6828' MD, Bttm OW 6842'. Full guage 6 3/4" hole to 6855'. UP wt 135k, DN wt 86k, Rot wt 100k, Tor 5-5.5k 10:00 10:15 0.25 6,855 6,855 PROD2 DRILL MILL P Work Mill thru window 3 times - No roblems or for noted. 10:15 11:15 1.00 6,855 6,855 PROD2 DRILL CIRC P Pump Wt/ Hi Vis sweep to recover and clean out metal cuttings - 250 gpm, 1900 psi, 50 rpms. Noted very good recove ma nets. 11:15 12:00 0.75 6,855 6,855 PROD2 DRILL CIRC P Flow ck well -Pump dry job -Blow do to drive 12:00 12:15 0.25 6,855 6,855 PROD2 DRILL SFTY P PJSM -Discuss TOH and all expected hazards 12:15 14:30 2.25 6,855 6,855 PROD2 DRILL TRIP P TOOH w/ Milling assy - UD bumper sub 14:30 15:00 0.50 6,855 6,855 PROD2 DRILL SRVY P Dn Load MWD -Monitor well "Static" 15:00 16:00 1.00 6,855 6,855 PROD2 DRILL PULD P UD MWD & Milling assy. Mills look good. Top mill ck "Full Guage" -Clear tools from ri floor 16:00 16:30 0.50 6,855 6,855 PROD2 WELCT BOPE P Set Test Plug -Fill BOPs and Choke Manifold w/ water - MU floor valves and test manifold 16:30 17:30 1.00 6,855 6,855 PROD2 WELCT BOPE P Pull wear bushing & flush stack with cleanin tool - UD tool -Drain stack 17:30 21:30 4.00 6,855 6,855 PROD2 WELCT BOPE P Test BOPS and Choke Manifold -Test atl components 250 psi Low and 3000 psi High. Make sure complete test is charted. All components tested good. See BOP test sheet for detail. Pull test plug. Install wear bushing - UD all testin tools and clear floor. 21:30 22:45 1.25 6,855 6,855 PROD2 DRILL PULD P PU BHA # 7 w/Geo Pilot per Sperry Sun detail w/ MDW.""' Note""' We are running the new Baker/Hughes HCR - 5052 box u bit. 22:45 23:30 0.75 6,855 PROD2 DRILL SRVY P Program MWD -Monitor well (Static) 23:30 00:00 0.50 PROD2 DRILL TRIP P PU Flt sub - TIH w/ BHA #7 06/13/2006 00:00 00:15 0.25 PROD2 DRILL SFTY P PJSM for Trip in hole, Discussed Hazzards & Communication with all hands. 00:15 00:45 0.50 PROD2 DRILL DHEQ P Break in Geo Pilot bearings, Surface test MWD &Geo Pilot "Geo Pilot Failed". 00:45 02:30 1.75 60 PROD2 DRILL PULD T POOH, Down load MWD, Break bit, Lay down Geo Pilot, Pick up new Geo Pilot, Make u bit, U load MWD. ~~ ~m®_®s ®~~ _m ®® ~~. 1 ~ oaf 2 ..~ Time Logs Date From To Dur ~ th E. De th Phase Code Subcode T OM 06/13/2006 02:30 03:00 0.50 60 453 PROD2 DRILL DHEO T RIH to 453', Break in Geo Pilot bearings, Shallow test MWD tools - OK 03:00 05:00 2.00 453 6,736 PROD2 DRILL TRIP P RIH f/ 453' to 6,736' (Filled pipe @ 2695', 5028' 05:00 05:15 0.25 6,736 6,864 PROD2 DRILL REAM P Run thru window @ 6,828', Ream down to 6,864' w/ 264 gpm @ 1900 si, 60 RPM, TQ 6K. 05:15 05:30 0.25 6,864 6,864 PROD2 DRILL SFTY P PJSM on Drilling and Making connections. 05:30 12:00 6.50 6,864 7,217 PROD2 DRILL DDRL P Drill f/ 6,864' to 7,217' MD 3,505' TVD (353'), ADT= 4.82 hrs, WOB 8/12K, RPM 120, Up 125K, Dn 60K, Rot 84K, Tq 6K on / 6K Off, Max gas 48 units, ECD's 10.2 ppg, Concretions 6916', 6923', 6941', 6944'. 12:00 12:15 0.25 7,217 7,217 PROD2 DRILL SFTY P Held PJSM with crew on Making connections and Pinch oints 12:15 00:00 11.75 7,217 8,667 PROD2 DRILL DDRL P Drill f/ 7,217' to 8,667' MD 3,510' TVD (1,450'), ADT= 8.84 hrs, WOB 10/12K, RPM 120, Up 135K, Dn 60K, Rot 85K, Tq 6-7K on / 6K Off, Max gas 92 units, ECD's 10.9 ppg, Concretions 8068'-8081', 8083'-8089', 8206'-8215', 8628'-8634'. 06/14/2006 00:00 00:15 0.25 8,667 8,667 PROD2 DRILL SFTY P Held PJSM with crew on hazard reco nition of tasks. 00:15 09:00 8.75 8,667 9,440 PROD2 DRILL DDRL P Drill f/ 8,667' to 9,440' MD 3,515' TVD (773'), ADT= 10.31 hrs, WOB 10/15K, RPM 120, 313 gpm @ 2800 psi, Up 135K, Dn 54K, Rot 84K, Tq 7K on / 8K Off, Max gas 125 units, ECD's 10.9 09:00 09:30 0.50 9,440 9,440 PROD2 DRILL CIRC T Circ hole clean for trip due to ROP Dro and unable to build an le. 09:30 11:30 2.00 9,440 7,219 PROD2 DRILL TRIP T Monitor well, POOH on elevators f/ 9,440' to 7,219' -Began pulling 25K over. 11:30 12:00 0.50 7,219 7,122 PROD2 DRILL REAM T Back Ream out of hole f/ 7,219' to 7,122' w/ 313 gpm @ 2300 psi & 120 RPM. 12:00 12:15 0.25 7,122 7,122 PROD2 DRILL SFTY T PJSM with crew on back reaming out of hole and related hazards. 12:15 12:30 0.25 7,122 6,760 PROD2 DRILL REAM T Back Ream out of hole f/ 7,122' to 6,929' w/ 313 gpm @ 2300 psi & 120 RPM, Pull to 6,760' thru window @ 6,828'-OK, Pum d 'ob. 12:30 14:30 2.00 6,760 30 PROD2 DRILL TRIP T POOH, Stand back BHA, Break Bit, Monitor well- OK. Note; Found Bit to have rin ed out in nose row. 14:30 15:00 0.50 30 30 PROD2 DRILL TRIP T Down load MWD tools. 15:00 15:30 0.50 30 30 PROD2 DRILL PULD T Change out GeoPilot & Make up Bit #5. 15:30 16:30 1.00 30 30 PROD2 DRILL TRIP T Program MWD tools, Change out float. ~_...----_ _ ~ ~ ~~~~: 'I ~ ~t ~7 Time Logs _ Date From To Dur th E. De th Phase Code Subcode T OM 06/14/2006 16:30 17:00 0.50 30 539 PROD2 DRILL TRIP T RIH w/ BHA to 539', Break in GeoPilot bearin s & Shallow test Tools- OK. 17:00 22:30 5.50 539 9,440 PROD2 DRILL TRIP T RIH to 6,960' (Filled pipe @ 3161' & 6736'), RIH to 9,440' - Wash & Reamed bridges @ 6960' to 7015', 7460' to 7510', 7606' to 7992', 8186' to 8282', 8863' to 9440'- Reamed w/ 300 m & 120 RPM. 22:30 00:00 1.50 9,440 9,590 PROD2 DRILL DDRL P Drill f/ 9,440' to 9,590' MD 3,505' TVD (150'), ADT= 1.00 hrs, WOB 8/12K, RPM 130, 310 gpm @ 2950 psi, Up 140K, Dn 54K, Rot 82K, Tq 6K on / 6K Off, Max gas 51 units, ECD's 11.1 06/15/2006 00:00 00:15 0.25 9,590 9,590 PROD2 DRILL SFTY P PJSM, Discussed hazard assessment of tasks. 00:15 12:00 11.75 9,590 10,315 PROD2 DRILL DDRL P Drill f/ 9,590' to 10,315' MD 3,501' TVD (725'), ADT= 9.21 hrs, WOB 10/15K, RPM 120, 313 gpm @ 2800 psi, Up 135K, Dn 50K, Rot 80K, Tq 7K on / 6K Off, Max gas 88 units, ECD's 10.75 ppg, Concretions= 9888'-9902', 9986'-10000', 10008'-10021', 10043'-10050', 10055'-10063', 10066'-10070', 10082'-10092', 10288'-10300', 10311'-10315'. 12:00 12:15 0.25 10,315 10,315 PROD2 DRILL SFTY P PJSM for Drlg ahead/Hazard reco nition 12:15 00:00 11.75 10,315 11,462 PROD2 DRILL DDRL P Drill f/ 10,315" to 11,462' MD 3,514' TVD (1,147'), ADT= 8.47 hrs, WOB 8/14K, RPM 130, 310 gpm @ 3,000 psi, Up 145K, Dn 40K, Rot 85K, Tq 7.5K on / 7K Off, Max gas 151 units, ECD's 11.42 ppg, Concretions= 10,450' - 10,455 - 10,898' - 10,902' - 10,908' - 10,910' - 10,915' - 10,918' - 10,929' - 10,934' - 11,060' - 11,066' - 11,196' - 11,205'. Total concretion foota e = 34' 06/16/2006 00:00 12:00 12.00 11,462 12,602 PROD2 DRILL DDRL P Drill 6-3/4" hole from 11,462' - 12,602' MD (3,552' tvd). ADT = 8.82 hrs. Pump 30 bbl hi-vis sweep at 12,561'. Concretions at 11,593 - 595', 11,870 - 872', 11,954-956', 12,030-038',12,193-207'. Total daily foota a of concretion drl = 28'. 12:00 12:15 0.25 12,602 12,602 PROD2 DRILL SFTY P PJSM for BROOH. 12:15 13:00 0.75 12,602 12,602 PROD2 DRILL CIRC P Circ sweep out at 310 GPM and 125 rpm, while reciprocating, with 5 excess cuttings. Survey. Monitor well - static. 13:00 20:30 7.50 12,602 6,736 PROD2 DRILL REAM P BROOH from 12,602' - 7,026'. POOH to inside of 7-5/8" csg to 6,736'. Monitor well -static. _ _ ~ .w ~ ~e ~' ~, ~7 ~ _.-. ~ . . ~..~.~~.~ ~ Time Lo~_ Date From To Dur th E. De th Phase Code Subcode T OM 06/16/2006 20:30 22:45 2.25 6,736 6,639 PROD2 DRILL CIRC P Pump 35 bbl Hi-Vis sweep. CBU 3x at 310 GPM and 80 rpm, while reci rcatin i e from 6,736-6,639'. 22:45 00:00 1.25 6,736 6,639 PROD2 DRILL OTHR P Cut and slip 70' of drill line. 06/17/2006 00:00 01:15 1.25 6,639 6,639 PROD2 DRILL OTHR P Change out Top Drive Saver sub. 01:15 03:00 1.75 6,639 9,733 PROD2 DRILL TRIP P RiH to 9,733' until ran out of down wei ht. 03:00 06:45 3.75 9,733 12,602 PROD2 DRILL REAM P Rotate at 90 rpm and wash in hole to 12,602' with 300 GPM, 2,700 psi and 7K ft-Ib of for ue. 06:45 08:30 1.75 12,602 12,602 PROD2 DRILL CIRC P Rack back stand in derrick and PU single jt from shed. Pump 30 bbl weighted Hi-Vis sweep at 12,591' with 130 rpm, 300 GPM, 3,200 psi, and 8,000 ft-Ib TQ. Increase in returns of 15%. 08:30 09:15 0.75 12,602 12,602 PROD2 DRILL CIRC P Displace B-Lateral hole to 8.7 ppg, 60/40 SFMOBM with 281 bbl, while rotating at 130 rpm, with 300 GPM and 7,500 ft-Ib of TQ. 09:15 12:00 2.75 12,602 8,379 PROD2 DRILL TRIP P Monitor well -static. Pump dry job. LD single. PU=165K, S0=0. POOH to 8,379' with hole takin ro er fill. 12:00 12:15 0.25 8,379 8,379 PROD2 DRILL SFTY P PJSM for POOH and LD BHA 12:15 14:30 2.25 8,379 359 PROD2 DRILL TRIP P Continue to POOH to HWDP at 359' (15K overpull at 6,830'). Monitor well - static. 14:30 15:00 0.50 359 0 PROD2 DRILL PULD P Flush MWD tools with 15 bbl of new LVT base mineral oil and stand back in derrick. 15:00 16:00 1.00 0 0 PROD2 DRILL PULD P Download MWD. 16:00 16:30 0.50 0 0 PROD2 DRILL PULD P Break bit, LD Geo-Pilot and MWD. Clear ri floor. 16:30 17:30 1.00 0 0 COMPZ DRILL PULD P PU/MU whipstock retrieving assembly. 17:30 20:00 2.50 0 6,791 COMPZ DRILL TRIP P RIH filling DP at 3,282'. Continue RIH to 6,791'. PU=130K, S0=70K. Break circ. 20:00 21:00 1.00 6,791 6,740 COMPZ DRILL OTHR P Wash and latch onto whipstock at 6,833'. Work and jar free. Maximum overpull = 85K (PU=215K). Jar free with PU=195K. POOH one stand to 6,740' with PU=140K. 21:00 22:00 1.00 6,740 6,740 COMPZ DRILL CIRC P Circ bottoms up with max gas = 41 units. Monitor well -static. Pum slu . 22:00 00:00 2.00 6,740 2,280 COMPZ DRILL TRIP P POOH 06/18/2006 00:00 01:00 1.00 2,280 60 COMPZ DRILL TRIP P Continue POOH 60' with whipstock. 01:00 03:00 2.00 60 0 COMPZ DRILL PULD P LD BHA, whipstock and trip anchor, with No-Go seal assembl . _ _ _~ s me _ -m ~~~a 13 ~,f ~7 ~. ~ _ ~ ® s~~ Time Low Date. From To Dur pth E. De th Phase Code Subcode T ~O_M 06/18/2006 03:00 03:30 0.50 0 0 COMPZ CASIN( RURD P Clear and clean rig floor. RU casing e ui . 03:30 03:45 0.25 0 0 COMPZ CASIN( SFTY P PJSM for running 4-1/2" liner. 03:45 06:45 3.00 0 5,726 COMPZ CASIN( RNCS P RIH with 132 joints R3, 4-1/2", 11.6 Ib/ft, L-80, BTC Blank/Slotted liner, with Hydroform centralizers on stop collars in the center of each joint. Tor ue rin s run in 'oints 55-132. 06:45 08:45 2.00 5,726 5,727 COMPZ CASIN( OTHR P MU liner swivel assembly, slimhole MWD, hook hanger and orient. PU = 75K, SO = 60K. 08:45 12:00 3.25 5,726 11,304 COMPZ CASIN( RUNL P RIH to 193' and shallow test MWD - good test. Continue RIH with liner and tag upon A-lateral at 6,976'. PU, orientate and pass through window on second attempt. RIH to 11,304'. PU=125K, S0=65K. 12:00 12:15 0.25 11,304 11,304 COMPZ CASIN( SFTY P PJSM for running liner. 12:15 13:00 0.75 11,304 12 COMPZ CASIN( RUNL P Continue RlH w/ liner to 12,465' (PU=160K, S0=40K). Broke circulation with 130 GPM at 1,200 si. 13:00 14:30 1.50 12,465 12,550 COMPZ CASIN( RUNL P Work liner to 12,560' with Hook 8' past window at 6,834'. PU, orient hook and work torque out of string. Set hook with all appearances of proper hook. PU with 35K in string weight loss. Shoe set at 12,550' and and TOL at 6,823' md. Monitor well -static. 14:30 17:30 3.00 12,550 0 COMPZ CASIN( RUNL P POOH with wet string. 17:30 18:30 1.00 0 0 COMPZ CASIN( OTHR P Pull and inspect liner running tool - okay. Clean rig floor. PU small handlin tools. 18:30 19:30 1.00 0 0 COMPZ CASIN( RURD P LD running tool and MWD. LD handling tools. 19:30 20:00 0.50 0 30 COMPZ CASIN( PUTB T PU casing tools and seal assembly for Hook hanger verification run. RD casin tools. 20:00 23:30 3.50 30 6,748 COMPZ CASIN( OTHR T RIH with seal assembly to 6,748' (PU= 130K, S0= 75K . 23:30 00:00 0.50 6,748 6,823 COMPZ CASIN( OTHR T Tag top of liner at 6,822.77'. 06/19/2006 00:00 01:00 1.00 6,823 6,930 COMPZ CASIN( OTHR T Tag top of liner at 6,822.77', Made 7 attempts to get inside TOL- No Good, Rotate at 10 RPM to get inside liner- OK, RIH & Tag top of Hook Hanger @ 6,823' -OK w/ Tail of seals 6,930'. 01:00 03:30 2.50 6,930 114 COMPZ CASIN( OTHR T POOH, pump dry job, continue POOH. 03:30 04:30 1.00 114 0 COMPZ CASIN( OTHR T LD BHA for hanger verification run. 04:30 06:30 2.00 0 743 COMPZ CASIN( PUTB P RU casing equipment, MU DB nipple, PU/MU LEM/ZXP assembl . 06:30 07:00 0.50 743 743 COMPZ CASIN( RURD P RD casing equipment. ~.~ ..__..- -_.._e... _~ --- ~~~ ~ ~sf ~ 7 1. _. _.._...._ ~ r Time Logs ` ~ _ -~ Date From. To Dur th E: Depth Phase Code Subcode T OM 06/19/2006 07:00 10:00 3.00 743 6,973 COMPZ CASIN( RUNL P _ RIH and Stab into A-lateral seal bore recepticle to 6,973'. Top of liner at 6,491' All measurements on depth Up 127K, Dn 80K, Observed LEM latch into position (Set 30K down on LEM), Pull test LEM to 10K over- OK, Reset 30K down on LEM. 10:00 11:00 1.00 6,973 6,973 COMPZ CASIN( RNCS P Drop ball and pump down at 127 GPM, 600 psi. Ball went on seat at 520 strokes. Pump and stage up to 4,000 si. Set acker. 11:00 11:15 0.25 6,973 6,973 COMPZ CASIN( OTHR P Pressure test ZXP to 1,000 psi for 5 minutes. 11:15 12:00 0.75 6,973 6,500 COMPZ CASIN( CIRC P CBU at 6,500' at 254 GPM and 1,500 si max as = 28 units . 12:00 12:15 0.25 6,500 6,500 COMPZ CASIN( SFTY P PJSM on POOH. Monitor well -static. 12:15 14:30 2.25 6,500 100 COMPZ CASIN( OTHR P POOH with running tools. 14:30 15:00 0.50 100 0 COMPZ CASIN( OTHR P LD running tools, clear rig floor. Monitor well -static. 15:00 15:30 0.50 0 0 PROD3 STK PULD P PU mills and whipstock. 15:30 17:00 1.50 0 150 PROD3 STK PULD P MU mills and whipstock assembly pinned with 35K shear bolt. PU/MU MWD and bum er sub. Orient MWD. 17:00 18:00 1.00 150 150 PROD3 STK OTHR P Upload MWD. 18:00 18:30 0.50 150 457 PROD3 STK TRIP P RIH to 457' and shallow pulse test MWD at 280 GPM and 900 si. 18:30 20:45 2.25 457 5,663 PROD3 STK TRIP P RIH w/ whipstock. Fill DP at 3,358'. Break circ at 5,663' 20:45 21:30 0.75 5,663 5,671 PROD3 STK OTHR P MAD pass across K-13 from 5,581'-5,671' md, and orient to 14 deg left. 21:30 21:45 0.25 5,671 6,437 PROD3 STK TRIP P RIH to 6,437'. PU 120K, S0= 78K. Break circulation. 21:45 22:30 0.75 6,437 6,410 PROD3 STK WPST P Orient whipstock to 20L, shear with 40K and set to at 6,409.5' tmd . 22:30 00:00 1.50 6,410 6,412 PROD3 STK MILL P Mill window 6,409.5 - 6,412' at 100 RPM, 235 GPM and torge = 4-6,000 ft-Ib. 06/20/2006 00:00 06:30 6.50 6,412 6,452 PROD3 STK MILL P Continue milling window from 6,412'-6,422' with 230 GPM, 1,650 psi 5 r~ ~-` © ~ and torque = 3-5,000 ft-Ib. Drill to 6,452' with 6-3/4" guaged hole to 6,442'. Work mills through window and dress off same. 06:30 09:00 2.50 6,452 92 PROD3 STK TRIP P Monitor well -static. POOH to 92'. 09:00 09:15 0.25 92 92 PROD3 STK PULD P LD BHA, XO and bumper sub 09:15 10:00 0.75 92 92 PROD3 STK OTHR P Download MWD. 10:00 10:30 0.50 92 0 PROD3 STK PULD P Continue LD BHA, MWD, Mills. Upper full ua a 6-3/4" mill in ua e. ~ e_____-- ~ ~- ~ e~ ~ ®___v.__-d ~~ _.._ ®® i.___~_ _... _ P~3,~ Time Logs Da e From To Dur th E: De th Phase Code Subcode T OM 06/20/2006 10:30 11:00 0.50 0 0 PROD3 STK OTHR P Clean and clear rig floor. 11:00 12:00 1.00 0 0 PROD3 DRILL PULD P PU/MU Rotary steerable tools, collar and LD to ether. Flush stack. 12:00 13:00 1.00 0 0 PROD3 DRILL SFTY P PJSM. Continue flushing stack. 13:00 13:45 0.75. 0 0 PROD3 DRILL OTHR P Pull WB, flush stack, set WB and LD tools. 13:45 14:15 0.50 0 56 PROD3 DRILL TRIP P RIH w/ bit and Rotary steerable tools, flex collar. PU MWD. 14:15 15:15 1.00 56 88 PROD3 DRILL OTHR P Upload MWD. Monitor well -static. 15:15 15:45 0.50 88 356 PROD3 DRILL TRIP P RIH w/ BHA, break in bearings and shallow ulse test MWD. 15:45 17:30 1.75 356 6,325 PROD3 DRILL TRIP P RIH filling DP at 3,159' and 6,325' 17:30 18:15 0.75 6,325 6,325 PROD3 DRILL SFTY P PJSM. Cut and Slip 72' of drill line. 18:15 18:45 0.50 6,325 6,452 PROD3 DRILL TRIP P RIH, pass thru window smoothly. Break circ at 6,429'. Ream from 6,429' - 6,452' with 90 rpm, 282 GPM, 2,000 si and 1-2,000 ft-Ib of for ue. 18:45 00:00 5.25 6,452 7,003 PROD3 DRILL DDRL P Drill ahead from 6,452' 7,003' tmd (3,439' tvd). ADT = 3.75 hr. PU = 120K, S0= 60K ROT= 81 K, TQ on/off = 6K/5-6K. ECDs = 10.2 ppg, Max Gas = 63 units. Concretions @ 6,565-6,572', 6,597 - 6,601', 6,754 - 6,759'. Total = 16'. 06/21!2006 00:00 12:00 12.00 7,003 8,020 PROD3 DRILL DDRL P Continue drilling 7,003 - 8,020' and (3,430' tvd). PU=130K, S0= 57K, ROT= 80K, TQ on/off = 6,000/7,000 ft-Ib, Press= 2,500 psi, ECD= 10.43 ppg, Max Gas = 109 units Concretions: 7,019-28', 7,037-39', 7,049-54', 7,130-136', 7,140-145', 7,159-167', 7,182-190', 7,214-216', 7,218-220', 7,242-255', 7,258-271', 7,308-320', 7,323-346', 7,405-410', 7514-517', 7,528-534', 7,598-602'. Total= 120'. 12:00 00:00 12.00 7,003 9,227 PROD3 DRILL DDRL P Continue drilling 8,020 - 9,227' and (3,432' tvd). PU=145K, S0= 57K, ROT= 85K, TO on/off = 6,500 ft-Ib, Press= 2,650 psi, ECD= 11.06 ppg, Max Gas = 92 units Concretions: 8,202-205', 8,258-280', 8,297-312', 8,405-420', 9,085-096', 9,122-129', 9,141-145' Total=81' 06/22/2006 00:00 12:00 12.00 9,227 10,427 PROD3 DRILL DDRL P Drill 6-3/4" D-lateral from 9,227-10,427' tmd (3,429' tvd) PU= 145K, S0= OK, ROT= 80K, Torque on/off = 8,000/8,500 ft-Ib, Max Gas= 224 units, ECD= 11.2 ppg Concretions: 9,875-90', 9,943-48', 10,047-54', 10,210-214', 10,220-223'. Total: 34' _ ~ ~~ ---- ~....~ -a°v~ `t ~# ~7 Time Logs _ ~ Date From To Dur th E. De th Phase Code Subcode T OM 06/22/2006 12:00 00:00 12.00 10,427 11,314 PROD3 DRILL DDRL P Drill ahead 6-3/4" D-lateral 10,427-11,314' tmd, (3,441' tvd) Concretions: 10,632-637', 10,870-72', 11,135-138', 11,150-163', 11,188-210', 11,218-232', 11-,240-252', 11,266-279', 11,284-292', 11,298-314', Total= 108' 06/23/2006 00:00 12:00 12.00 11,314 12,050 PROD3 DRILL DDRL P Drill 6-3/4" D-lateral 11,314-12,050' tmd (3,477' tvd). ART= 9.15 hr PU= 155K, S0= OK, ROT= 80K Torque OnlOff = 9,00019,000 ft-Ib Press= 3,050 psi, ECD= 11.45 ppg Max Gas= 132 units Concretions: 11,328-345', 11,348-357', 11,659-666', 11,681-693', 11,705-708', 11,775-778', 11,831-838', 11,847-850', 11,853-867', 11,902-913', 11,926-939' Total= 73' 12:00 18:30 6.50 12,050 12,678 PROD3 DRILL DDRL P Drill 6-3/4" D-lateral 12,050-12,678' tmd (3,484' tvd). ART= 5.19 hr PU= 170K, S0= OK, ROT= 85K Torque On/Off = 9,000/10,000 ft-Ib Press= 3,300 psi, ECD= 11.80 ppg Max Gas= 70 units Concretions: Total= 0 18:30 19:15 0.75 12,678 12,678 PROD3 DRILL CIRC P Circulate weighted Hi-Vis sweep at 310 GPM, 3,375 psi with a 20% increase in cuttings returns. Survey hole at TD. 19:15 19:30 0.25 12,678 12,647 PROD3 DRILL OWFF P LD single joint, monitor well -static. 19:30 00:00 4.50 12,647 10,294 PROD3 DRILL REAM P BROOH 12, 647-10,294' at 310 GPM, 3,150--3,000 psi, 100 RPM, and 40-45 ft/min. Average torque= 8,000 ft-Ib, PU=90K. Lost 9.7 bbl while BROOH. 06/24/2006 00:00 04:30 4.50 10,294 6,429 PROD3 DRILL REAM P Continue BROOH 10,294 - 6,429' at drilling rate. Pull thru window w/o roblems. PU= 120K, S0= 35K 04:30 06:30 2.00 6,429 6,336 PROD3 DRILL CIRC P Pull inside window to 6,336', pump 30 bbl weighted sweep plus 3 btms up at 300 GPM, 100 RPM, torque= 45,000 ft-Ib. 06:30 09:30 3.00 6,336 10,197 PROD3 DRILL TRIP P RiH. Slide through window without problems. RIH to 8,940 washing thru tight spot to 9,000'. Continue RIH to 10,197' where slackoff wt = 0. 09:30 12:00 2.50 10,197 10,918 PROD3 DRILL REAM P Wash and ream 10,197-918' at 305 GPM, 3,000 si and 100 RPM. 12:00 12:45 0.75 10,918 12,678 PROD3 DRILL REAM P Continue wash and reaming to TD at 12,678' tmd, at 305 GPM, 3,100 psi, 100 r m amd 4,000 ft-lb. 12:45 14:15 1.50 12,678 12,678 PROD3 DRILL CIRC P Pump 35 bbl weighted Hi-Vis sweep at 275 - 310 GPM, 2,900-3,450 psi, 140 rpm with no increase in cuttings returns. 14:15 15:00 0.75 12,678 12,678 PROD3 DRILL CIRC P Displace open hole with 298 bbl of 60/40, 8.7 ppg, SFMOBM. Chase with OBM and d ~ob. -~a -m ~~_ _ _...- __,...A. P~~ 2 ~sfi 27 Time Logs ~---- Date From To Dur t~ h E. De tp h Phase Code Subcode T OM 06/24/2006 15:00 15:15 0.25 12,678 12,650 PROD3 DRILL PULD P LD single and flow check well -okay. 15:15 20:30 5.25 12,650 359 PROD3 DRILL TRIP P Drop rabbit and POOH on elevators. Inspect Lo-TADS and Super-Sliders. Calculated displacement 73.1 bbl, actual displacement 94.1 bbl. Pulled 30K over throu h ti ht s of at 9,005'. 20:30 21:30 1.00 359 60 PROD3 DRILL PULD P LD HWDP and collars in BHA. 21:30 00:00 2.50 60 60 PROD3 DRILL OTHR P Download MWD and LD same. Function tested Blind Rams. 06/25/2006 00:00 00:30 0.50 60 0 PROD3 DRILL PULD P Continue LD MWD and BHA. 00:30 01:00 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 01:00 01:45 0.75 0 0 COMPZ CASIN( RURD P RU 4-1/2" casing equip., hold PJSM 01:45 05:15 3.50 0 6,329 COMPZ CASIN( RUNL P RIH with 141 Jts of 4-1/2", 11.6 Ib/ft, L-80, BTC-M slotted /blank liner, with 6.125 x 4.5" Hydroform centralizers, free floatin . 05:15 06:00 0.75 6,329 6,359 COMPZ CASIN( CIRC P PU/MU seal bore receptacle, HR liner runnin tool and XO. 06:00 06:15 0.25 6,359 6,359 COMPZ CASIN( PUTB P RD casing tools. 06:15 09:45 3.50 6,359 12,489 COMPZ CASIN( RUNL P RIH to 6,390'. Rotate liner at 25 RPM with 2,500 ft-Ib and 85K ROT wt. Continue RIH to 12,250' where SO wt went to zero. Floated casing to 12,489'. 09:45 10:15 0.50 12,489 12,685 COMPZ CASIN( RUNL P Rotate liner from 12,489 - 12,623', PU 2 joints from shed, tagging bottom at 12,685', PU 170K, S0= OK, ROT= 95K, TQ = 8-9,000 ft-Ib at 10 RPM. 10:15 11:00 0.75 12,685 12,685 COMPZ CASIN( RUNL P Set liner on depth, drop ball and pump down, seating at 645 strokes, slackoff with 50K, shear ball seat at 4,500 si. 11:00 11:15 0.25 12,685 6,371 COMPZ CASIN( OTHR P LD 2 joints of DP. 11:15 12:00 0.75 6,371 6,371 COMPZ CASIN( CIRC P CBU at 6,371' with 305 GPM, and 1,950 si. 12:00 12:15 0.25 6,371 6,371 COMPZ CASIN( OTHR P Pump dry job, monitor well -static. 12:15 14:30 2.25 6,371 0 COMPZ CASIN( OTHR P POOH, LD running tool removed one bad Lo-TAD from stand #10. Calc displacement on POOH = 51.2 bbl vs. 52.4 bbl actual. 14:30 15:00 0.50 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. 15:00 16:00 1.00 0 0 COMPZ WELCT BOPE P Pull WB, rig up test joint and test equip, MU floor valves. Repair lockdown screw and gland nut in wellhead. Time Lo~_ Date From To Dur ~oth'rE. Death Phase Code Subcode T OM ~ 06/25/2006 16:00 19:00 3.00 0 0 COMPZ WELCT BOPE P Test all valves in choke manifold, Annular preventer, top pipe rams, upper and. lower IBOP valves, manual and HCR choke and kill valves, 4" floor and dart valves to 250 low and 3,000 psi high, holding 5 minutes for low and high each. Perform accumulator function test, before 3,000 psi, after closing 2,000 psi, 200 psi buildup in 44 sec, and full charge in 2 min, 46 sec. Five nitrogen bottles -average of 2,350 psi. Blow down choke manifold and lines line backu for drillin . 19:00 20:00 1.00 0 0 COMPZ WELCT BOPE P RD test equipment, install WB 20:00 20:30 0.50 0 330 COMPZ FISH PULD P PJSM, MU whipstock retrieval BHA. 20:30 00:00 3.50 330 6,414 COMPZ FISH TRIP P RIH to retrieve whipstock. Remove Lo-TAD from stand #10. Fill pipe every 20 stds, calculated fill 46.6 bbl, actual = 39.7 bbl. Circulate and wash over whipstock slot at 250 GPM, 1,240 psi, rotating at 20 RPM, TQ= 3-4,000 ft-Ib, ROT= 97K Note: GBR and Frank's Casing took measurements on the rig for a h draulic casin stabber. 06/26/2006 00:00 04:45 4.75 6,414 6,331 COMPZ FISH FISH P Continue to attempt to hook whipstock washing from 6,409 - 6,425'. Hook whipstock twice, pull to 190K, fired jars and pulled free. POOH to 6,331'. Weight before hooking = 135K, after= 125K. 04:45 05:45 1.00 6,331 6,331 COMPZ FISH CIRC P Circulate at 6,331' with 210 GPM and 1,250 si. Monitor well -static. 05:45 09:15 3.50 6,331 59 COMPZ FISH TRIP P POOH to 59'. 09:15 11:00 1.75 59 0 COMPZ FISH PULD P LD BHA XO, Jar, Bumper Jar, 1 JT 3-1/2" HWDP, hook, whipstock, trip anchor assembly w/ No-Go Seal assembl . 11:00 11:30 0.50 0 0 COMPZ FISH OTHR P Clear and clean rig floor. 11:30 12:00 0.50 0 0 COMPZ CASIN( CIRC P PU casing equipment and slim hole MWD. 12:00 12:30 0.50 0 0 COMPZ CASIN( RURD P RU to run hook hanger. PU / RU, power tongs, crummies and false rota tabe. 12:30 12:45 0.25 0 0 COMPZ CASIN( RURD P PJSM for PU Hook Hanger 12:45 14:45 2.00 0 31 COMPZ CASIN( PUTB P MU hook hanger assembly and MWD. U load MWD. 14:45 18:45 4.00 31 6,407 COMPZ CASIN( RUNL P Run hook hanger and No-Go on XO below seal bore at 6,530' in the B-Lat liner. POOH to above window, PU= 130K, S0= 79K. ,®._~.. ®_ v _..._ ~m ~ ~. ~~ ~~ s~€ ~ Time Logs Date From_ To Dur th E. Depth Phase Code Subcc~de T M 06/26/2006 18:45 20:30 1.75 31 6,407 COMPZ CASIN( RUNL P Orient to 2 deg right, pass thru window on second attempt, RIH and hook 58.75' in on stand with 30K of down weight. Hanger oriented itself to 1 deg left. PU, turn 180 deg, RIH 67' in on stand and tag XO below the 5-1l2" receptacle joint (1,95' low). PU, turn hanger string, orienting to 19 degrees left. RIH 57.5' in on stand where hanger started taking weight and self oriented to 4 deg left. SO with 35K at 59' in on stand. Hook hanger set at 6407.44' tmd. Circulate and drop ball pumping down to ball seat. Pressure up to 2,800 psi and inflate ECP, continure pressure up to 4,500 psi and release from hanger and ECP. PU wt = 120K after, 130K before. 20:30 20:45 0.25 6,407 6,407 COMPZ CASIN( CIRC P Pump slug. Monitor well -static. 20:45 00:00 3.25. 6,407 0 COMPZ CASIN( RUNL P POOH to slimhole MWD, download and LD. Displacement calculated = 52.3 bbl, Actual displacement = 50.8 bbl. 06/27/2006 00:00 00:45 0.75 15 0 COMPZ CASIN( RUNL P UD Baker Hook Hanger running tools, UD Slim hole Sperry Sun MWD, UD inner wash strin . 00:45 01:15 0.50 0 0 COMPZ CASIN( RURD P Remove all tools from rig floor, Slim Hole MWD tools to i e shed 01:15 01:30 0.25 0 0 COMPZ CASIN( RURD P Clean and Power wash rig floor and rota area. 01:30 02:30 1.00 0 0 COMPZ RIGMN SVRG P PJSM -Slip and Cut drill line (79' cut) 02:30 03:00 0.50 0 0 COMPZ CASIN( RURD P PJSM - R/U Csg running tools 03:00 04:00 1.00 0 182 COMPZ CASIN( RNCS P M/U LEM assy per detail ,Bent Jt w/ seals, 1 jt 4.5" Tbg, 2 pup jts, LEM, Seal bore, ZXP 04:00 07:15 3.25 182 6,521 COMPZ CASIN( RNCS P TIH w/ LEM assy on DP to 6521' MD, Up wt 127k, Dn wt 77k, TOL @ 6353' MD 07:15 08:00 0.75 6,521 6,521 COMPZ CASIN( CIRC P Drop Ball & Pump down @ 3 BPM, 600 psi, 125 gpm, 36 spm, Ball on seat @ 25 stks, SO to 40k & pressure up to 3000 psi, set liner top packer, continue pressure up to 4000 psi and release from LEM. 08:00 09:00 1.00 6,521 6,420 COMPZ CASIN( RUNL P POOH T/6420' MD, CBU @ 72 spm, 250 gpm, 1550 psi, Up wt = 125k, Dn wt = 75k 09:00 12:00 3.00 6,420 1,145 COMPZ CASIN( RUNL P Monitor well, Pump Dry Job, POOH t/ 1145' cleaning OBM off off Super Sliders and Lo-TADs 12:00 12:15 0.25 1,145 0 COMPZ CASIN( RUNL P Continue POOH f/1145' to Surface 12:15 12:30 0.25 0 0 COMPZ CASIN( RURD P UD Running Tool _ ~_ ~ ~ ~ e~ age ~v ~ 7 ~. _ Time Logs Date From To Dur _ th E. De th Phase Code Subcode T OM 06/27/2006 12:30 13:00 0.50 0 0 COMPZ RPCOh RURD P Pull wear ring 13:00 14:00 1.00 0 0 COMPZ RPCOh RURD P Clear and Clean Rig Floor & RU to run 4.5" IBT Com letion Strin 14:00 14:15 0.25 0 0 COMPZ RPCOti SFTY P PJSM/ Hazard Assesment meeting w/ Co Rep, Toolpusher, Rig Crew & Casin Hand on runnin tubin 14:15 19:30 5.25 0 6,387 COMPZ RPCOh RCST P Run 204 jts Tubing and Jewlery, PU Wt = 82k, SO Wt = 59k 19:30 20:00 0.50 6,383 6,383 COMPZ RPCOh HOSO P Run In, Tag Up, Space out 4' from being fully inserted, come out, PU Space Out Pups & Landing Jt w/ Hanger. Mule shoe of completion @ 6382.65' -Seals 4' from fully inserted. U wt 82k, SO wt 59k 20:00 20:30 0.50 6,383 6,383 COMPZ RPCOh HOSO P Orient and Land Tubing on Hanger & RI-LDS 20:30 22:30 2.00 6,383 6,383 COMPZ RPCOh SFEO P Sim-Ops, UD Landing Jt, Test Upper & Lower Hanger Body Seals to 5000 psi for 15 min, UD Casing tools, Clear & Clean Rig Floor, Remove Bell Nipple, Start Flushing Pits, Mud S stem, and Geo-S an w/ H2O 22:30 00:00 1.50 6,383 6,383 COMPZ RPCOh NUND P De-Energize, Drain BOPE stack & start Ni lin Down 06/28/2006 00:00 02:00 2.00 0 0 COMPZ RPCOh NUND P Nipple up tree, Test tubing bonnet and tree to 5000 si for 10 min. 02:00 02:30 0.50 0 0 COMPZ RPCOh NUND P Pull two-way check 02:30 07:00 4.50 0 0 COMPZ RPCOh PULD P PJSM - R/U mouse hole UD 4" DP from derrick 153 'ts 07:00 07:45 0.75 0 0 COMPZ RPCOh RURD P R/U Hot Oil 07:45 08:00 0.25 0 0 COMPZ RPCOh CIRC P PJSM w/ Rig crew and HOt Oil on dis lacin well with diesel. 08:00 10:00 2.00 0 0 COMPZ RPCOh FRZP P Pressure Test lines to 2000 psi, displace well with 310 BBLs diesel @ 4 BPM, 1250 psi, R/D Hot Oil. Freeze protect pumped thru sliding sleeve @ 6309' MD. Diesel in Tbg & Annulus to 6309' MD. 10:00 11:00 1.00 0 0 COMPZ RPCOh RURD P R/U Scaffolding and Lubricator 11:00 12:00 1.00 0 0 COMPZ RPCOh NUND P Set BVP, R/D Lubricator 12:00 12:30 0.50 0 0 COMPZ RPCOti NUND P UD Lubricator, install tree cap, PJSM & Hazard assesment on UD drill pipe using mousehole, also UD Lo-TADs, remove scaffoldin . 12:30 21:30 9.00 0 0 COMPZ RPCOh RURD P Some-Ops cleaning pits, R/W, Preparing for Rig Move, off Hi-Line power @ 14:00 hrs, UD 25 stands slick, 15 stands Hybrids, 50 stands DP w/ Lo-TADS . es..~ ~ ~ ~ ~sw .~m _ __...~ ._. ~~ ~ ~__ _ ~ ~'~ge 1~ f "~ Time Lo s Date From To Dur th E. D_ e~th Phase Code Subcode T OM __ 06/28/2006 21:30 00:00 2.50 0 0 COMPZ RPCOh RURD P Blow Down Rig, Break service lines, prepare to jack rig and move off well. ""*"Note*""" Release Rig @ 2400 hrs Midni ht 6/28/2006 -Move to 1J-156 ~ a~~~ 27 gat ~? ~. ~.~.... ~-_.____~-°~ Halliburton Company* Survey Report (~nnihnn}: ConucoPhillipsAlas~:a Inr. I)ntc: 7%13r200~ 7imc: 09:27.10 I'a~~r: Iicld: Kupanik R iver Unit C u-unlinatc(\1_I 12efercncc: We;l 1J-170. T rue North ~itc: Kuparuk 1 J Pad ~ rrticail ("Ill)) Kcfrrcucc: 1J-170 109.0 \1cll: 1J-170 ~ cctiuu 1~~1 kcfcrcncc Well i0.00N.0-O OEO-OOAzi) 1lclil~a[h: 1J-170 ti unc~ (alculatiun ~Icthud: Minimum Curvature i)h: Orade Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Se a Level Geomagnetic Model: bggm2005 Well: 1 J-170 Slot Name: Well Position: +N/-S -305.03 ft Northing: 5945614.10 ft Latitude: 70 15 43.258 N +E/-W -70.73 ft Easting : 558 721.61 ft Longitude: 149 31 31.065 W Position Un certainty: 0.00 ft Wellpath: 1J-170 Drilled From: 1J-170PB2 500292331000 Tie-on Depth: 11226.90 ft Current Da tum: 1 J-170: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic D ata: 5/23/2006 Declination: 24.08 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section: De pth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Def-nitive Wellpath Date:. 7/13/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 50.00 732.00 1J-170P61 gyro (50 .00-732.00) CB-GYRO-SS Camera based gyro single shot 803.23 7859.80 1J-170PB1 (803.23-9246.96) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7940.00 11226.90 1J-170P62 (7940.00-11881.26) ( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11280.00 12444.74 1J-170 (11280.00-12444.74) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey III) Licl dint llI) ~~sllU A7~ Er~~~ ~lap.A ~lspl~_ Tnul ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945614.10 558721.61 • TIE LINE l 50.00 0.25 25.67 50.00 -59.00 0.04 0.02 5945614.14 558721.63 CB-GYRO-SS 100.00 0.25 22.52 100.00 -9.00 0.24 0.11 5945614.34 558721.72 CB-GYRO-SS 172.00 0.58 33.07 172.00 63.00 0.69 0.37 5945614.80 558721.97 CB-GYRO-SS 267.00 0.88 313.81 266.99 .157.99 1.60 0.10 5945615.70 558721.70 CB-GYRO-SS 358.00 3.08 287.40 357.93 248,93 2.82 -2.73 5945616.89 558718.86 CB-GYRO-SS 450.00 5.60 270.56 449.67 340.67 3.60 -9.58 5945617.62 558712.00 CB-GYRO-SS 540.00 7.50 260.08 539.08 430.08 2.63 -19.76 5945616.58 558701.83 CB-GYRO-SS 632.00 9.14 250.71 630.11 521.11 -0.82 -32.57 5945613.03 558689.05 CB-GYRO-SS 732.00 12.79 234.79 728.29 619.29 -9.83 -49.12 5945603.89 558672.57 CB-GYRO-SS 803.23 14.79 229.29 797.47 688.47 -20.31 -62.46 5945593.31 558659.32 MWD+IFR-AK-CAZ-SC 857.48 15.67 226.57 849.81 740.81 -29.86 -73.03 5945583.67 558648.83 MWD+IFR-AK-CAZ-SC 948.06 20.33 228.41 935.93 826.93 -48.73 -93.69 5945564.65 558628.31 MWD+IFR-AK-CAZ-SC 1041.06 24.31 230.15 1021.95 912.95 -71.72 -120.48 5945541.44 558601.70 MWD+IFR-AK-CAZ-SC 1134.20 28.34 230.76 1105.41 996.41 -98.00 -152.33 5945514.92 558570.06 MWD+IFR-AK-CAZ-SC 1225.44 33.10 230.11 1183.83 1074.83 -127.70 -188.24 5945484.95 558534.39 MWD+IFR-AK-CAZ-SC 1318.35 37.47 231.40 1259,65 1150.65 -161.62 -229.82 5945450.71 558493.08 MWD+IFR-AK-CAZ-SC 1410.82 40.50 233.18 1331.52 1222.52 -197.17 -275.85 5945414.81 558447.34 MWD+IFR-AK-CAZ-SC 1504.40 42.52 233.73 1401.60 1292.60 -234.09 -325.67 5945377.50 558397.80 MWD+IFR-AK-CAZ-SC 1596.02 46.06 233.75 1467.17 1358.17 -271.92 -377.25 5945339.27 558346.53 MWD+IFR-AK-CAZ-SC 1689.22 45.31 233.86 1532.28 1423.28 -311.30 -431.07 5945299.47 558293.02 MWD+IFR-AK-CAZ-SC 1782.35 50.09 232.99 1594.94 1485.94 -352.35 -486.36 5945258.00 558238.06 MWD+IFR-AK-CAZ-SC 1873.86 55.20 232.89 1650.44 1541.44 -396.18 -544.38 5945213.73 558180.38 MWD+IFR-AK-CAZ-SC 1966.96 58.05 234.02 1701.66 1592.66 -442.46 -606.84 5945166.97. 558118.29 MWD+IFR-AK-CAZ-SC 2061.56 61.81 234.48 1749.05 1640.05 -490.27 -673.28 5945118.64 558052.24 MWD+IFR-AK-CAZ-SC 2153.34 66.94 235.16 1788.73 1679.73 -537.93 -740.90 5945070.46 557985.00 MWD+IFR-AK-CAZ-SC 2245.85 68.35 235.35 1823.91 1714.91 -586.69 -811.20 5945021.16 557915.09 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report <~uup;un: ConocoPhillipsAlaska lnc. Iruc: ii13i200o liwc: 0927'10 Pac: '_ Ficlil: Kuparuk River Unit (~~-ur~linatclAl:) I:cicrcncc: Well: 1J-170, True North tii~c: Kuparuk 1J Pad ~'crlic,il ("I FI)~ Kcfcrrncc: 1J-170:109.0 ~\cll: 1J-170 ticclfun f~~) lirfcrcuec Well (0-OON O OOEO OOA~iI ~~'cllp:uh: 1J-170 ~~un~ct (alculatiun VrUu~~l: Minimum Curvature I11~: Oracle tiur~rc '<IU lurl ~iiui ICI) Vic, I~~ I) \;ti I~_A~ ~Ia~~A ~Lt~if Inul ft deg deg ft ft ft ft ft ft 2340.01 66.55 234.38 1860.02 1751.02 -636.73 -882.31 5944970.57 557844.37 MWD+IFR-AK-CAZ-SC 2430.35 66.09 233.38 1896.31 1787.31 -685.49 -949.14 5944921.29 557777.93 MWD+IFR-AK-CAZ-SC 2524.20 66.73 232:33 1933.86 1824.86 -737.43 -1017.70 5944868.83 557709.79 MWD+IFR-AK-CAZ-SC 2617.29 65.63 232.42 1971.46 1862.46 -789.42 -1085.15 5944816.32 557642.76 MWD+IFR-AK-CAZ-SC 2708.83 65.47 232.71 2009.35 1900.35 -840.07 -1151.32 5944765.16 557576.99 MWD+IFR-AK-CAZ-SC 2801.61 66.32 234.48 2047.24 1938.24 -890.33 -1219.48 5944714.38 557509.23 MWD+IFR-AK-CAZ-SC 2893.74 64.53 235.05 2085.56 1976.56 -938.66 -1287.90 5944665.51 557441.19 MWD+IFR-AK-CAZ-SC 2988.02 66.31 235.05 2124.77 2015.77 -987.78 -1358.18 5944615.86 557371.31 MWD+IFR-AK-CAZ-SC 3074.18 65.18 236.36 2160.17 2051.17 -1032.04 -1423.07 5944571.09 557306.77 MWD+IFR-AK-CAZ-SC 3105.86 63.95 236.54 2173.77 2064.77 -1047.85 -1446.91 5944555.10 557283.05 MWD+IFR-AK-CAZ-SC 3200.29 64.63 235.81 2214.74 2105.74 -1095.21 -1517.59 5944507.19 557212.75 -MWD+IFR-AK-CAZ-SC 3291.60 63.12 238.30 2254.95 2145.95 -1139.80 -1586.37 5944462.07 557144.33 MWD+IFR-AK-CAZ-SC 3384.37 63.59 241.70 2296.56 2187.56 -1181.25 -1658.17 5944420.07 557072.86 MWD+IFR-AK-CAZ-SC 3478.44 63.52 245.56 2338.47 2229.47 -1218.65 -1733.61 5944382.09 556997.72 MWD+IFR-AK-CAZ-SC 3572.09 64.29 249.70 2379.67 2270.67 -1250.64 -1811.37 5944349.50 556920.23 MWD+IFR-AK-CAZ-SC 3666.38 63.60 255.60 2421.12 2312.12 -1275.90 -1892.17 5944323.61 556839.63 MWD+IFR-AK-CAZ-SC 3761.00 63.46 .260.73 2463.32 2354.32 -1293.26 -1975.03 5944305.60 556756.92 MWD+IFR-AK-CAZ-SC 3853.11 64.39 266.07 2503.83 2394.83 -1302.75 -2057.17 5944295.47 556674.86 MWD+IFR-AK-CAZ-SC 3946.84 67.20 273.93 2542.30 2433.30 -1302.69 -2142.56 5944294.87 556589.48 MWD+IFR-AK-CAZ-SC 4039.97 65.00 278..25 2580.05 2471.05 -1293.68 -2227.20 5944303.21 556504.78 MWD+IFR-AK-CAZ-SC 4133.23 64.70 281.87 2619.69 2510.69 -1278.94 -2310.30 5944317.30 556421.57 MWD+IFR-AK-CAZ-SC 4224.53 63.44 282.61 2659.61 2550.61 -1261.54 -2390.54 5944334.08 556341.21 MWD+IFR-AK-CAZ-SC 4319.36 66.10 283.59 2700.03 2591.03 -1242.09 -2474.08 5944352:87 556257.53 MWD+IFR-AK-CAZ-SC 4412.60 66.79 282.94 2737.29 2628.29 -1222.48 -2557.27 5944371.83 556174.19 MWD+IFR-AK-CAZ-SC 4505.54 67.18 282.40 2773.63 2664.63 -1203.72 -2640.73 5944389.94 556090.60 MWD+IFR-AK-CAZ-SC 4601.05 67.18 284.97 2810.68 2701.68 -1182.89 -2726.26 5944410.10 556004.92 MWD+IFR-AK-CAZ-SC 4690.50 66.73 288.90 2845.71 2736.71 -1158.93 -2804.98 5944433.45 555926.02 MWD+IFR-AK-CAZ-SC 4780.83 65.35 293.36 2882.40 2773.40 -1129.20 -2881.95 5944462.57 555848.83 MWD+IFR-AK-CAZ-SC 4879.54 64.12 298.89 2924.56 2815.56 -1089.93 -2962.07 5944501.21 555768.42 MWD+IFR-AK-CAZ-SC 4972.71 63.90 302.49 2965.40 2856.40 -1047.20 -3034.07 5944543.37 555696.09 MWD+IFR-AK-CAZ-SC .5068.22 64.61 .306.75 3006.90 2897.90 -998.33 -3104.84 5944591.68 555624.95 MWD+IFR-AK-CAZ-SC 5160.02 64.66 312.00 3046.25 2937.25 -945.73 -3168.93 5944643.78 555560.46 MWD+IFR-AK-CAZ-SC 5254.34 67.22 318.22 3084.73 2975.73 -884.73 -3229.63 5944704.30 555499.28 .MWD+IFR-AK-CAZ-SC 5345.64 67.73 323.79 3119.73 3010.73 -819.21 -3282.67 5944769.39 555445.74 MWD+IFR-AK-CAZ-SC 5438.98 67.21 329.57 3155.52 3046.52 -747.21 -3330.01 .5944841.02 555397.85 MWD+IFR-AK-CAZ-SC 5533.31 68.47 335.37 3191.13 3082.13 -669.78 -3370.35 5944918.13 555356.91 MWD+IFR-AK-CAZ-SC 5625.93 72.12 341.26 3222.37 3113.37 -588.79 -3402.50 5944998.85 555324.13 MWD+IFR-AK-CAZ-SC 5719.45 72.25 346.61 3251.01 3142.01 -503.27 -3427.12 5945084.17 555298.84 MWD+IFR-AK-CAZ-SC 5814.69 73.89 352.76 3278.76 3169.76 -413.68 -3443.41 5945173.62 555281.86 MWD+IFR-AK-CAZ-SC 5907.49 75.91 358.77 3302.96 3193.96 -324.38 -3450.00 5945262.86 555274.58 MWD+IFR-AK-CAZ-SC 6000.27 78.27 359.79 3323.69 3214.69 -233.96 -3451.13 5945353.26 555272.74 MWD+IFR-AK-CAZ-SC 6093.70 78.76 359.45 3342.29 3233.29 -142.40 -3451.74 5945444.80 555271.42 MWD+IFR-AK-CAZ-SC 6186.46 79.63 358.81 3359.68 3250.68 -51.30 -3453.12 5945535.88 555269.32 MWD+IFR-AK-CAZ-SC 6280.24 78.96 357.80 3377.10 3268.10 40.81 -3455.85 5945627.96 555265.88 MWD+IFR-AK-CAZ-SC 6371.85 79.47 357.84 3394.24 3285.24 130.74 -3459.27 5945717.84 555261.76 MWD+IFR-AK-CAZ-SC 6466.74 78.89 358.55 3412.05 3303.05 223.89 -3462.21 5945810.97 555258.09 MWD+IFR-AK-CAZ-SC 6558.69 79.15 0.20 3429.57 3320.57 314.15 -3463.19 5945901.20 555256.41 MWD+IFR-AK-CAZ-SC 6654.07 79.53 0.30 3447.21 3338.21 407.88 -3462.78 5945994.93 555256.09 MWD+IFR-AK-CAZ-SC 6748.08 79.92 1.52 3463.98 3354.98 500.37 -3461.31 5946087.42 555256.83 MWD+IFR-AK-CAZ-SC 6839.78 79.97 2.18 3479.99 3370.99 590.61 -3458.40 5946177.67 555259.04. MWD+IFR-AK-CAZ-SC 6932.31 77.70 1.79 3497.91 3388.91 681.33 -3455.25 5946268.40 555261.48 MWD+IFR-AK-CAZ-SC 7026.06 80.25 2.03 3515.83 3406.83 773.29 -3452.18 5946360.38 555263.83 MWD+IFR-AK-CAZ-SC 7120.19 81.46 1.85 3530.79 3421.79 866.17 -3449.04 5946453.27 555266.25 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (rnnp:ui~: ConoroPhillipsAlasFa Inc. Uafc: 711~!20D6 Tiinc: 092710 Pair: 3 Piclil: Kuparuk River Unit Cu-unlinalclAI:) Kcfcrrncc: Well: 1J-170. True North tiilc: Kuparuk 1J Pad V'cr~ical (Il I)~ Kcfcrcncc: 1J-1 i0 109.0 ~~cll: 1J-1~0 ~cc(iu^ 1~~~1 Hrlcrencc Well 10 00N.O OOEO.OCAzi) ~1cllpath: 1J-170 tiur~~c~ (~alaila[ion ~lcduxl: Minimum Curvature Uh: Oracl2 ~tim~~ c~ III) lncl \iim Ill) ~cx Il~ll \,:ti F, ~~' ~I;i~iA ~IaEiF: lnul ft deg deg ft ft ft ft ft ft 7212.95 80.71 1.51 3545.17 3436.17 957.77 -3446.35 5946544.88 555268.23 MWD+IFR-AK-CAZ-SC ~ 7308.21 81.13 1.24 3560.20 3451.20 1051.81 -3444.10 5946638.92 555269.75 MWD+IFR-AK-CAZ-SC 7399.75 81.48 2.49 3574.04 3465.04 1142.25 -3441.15 5946729.37 555271.99 .MWD+IFR-AK-CAZ-SC 7492.77 79.85 4.14 3589.13 3480.13 1233.88 -3435.85. 5946821.03 555276.58 MWD+IFR-AK-CAZ-SC .7587.32 79.37 4.72 3606.18 3497.18 1326.60 -3428.66 5946913.79 555283.04 MWD+IFR-AK-CAZ-SC 7680.09 80.34 5.23 3622.52 3513.52 1417.57 -3420.74 5947004.82 555290.25 MWD+IFR-AK-CAZ-SC 7772.11 80.45 4.38 3637.88 3528.88 1507.98 -3413.14 5947095.28 555297.14 MWD+IFR-AK-CAZ-SC 7859.80 86.59 7.19 3647.77 3538.77 1594.62 -3404.35 5947181.97 555305.25 MWD+IFR-AK-CAZ-SC 7940.00 88.04 9.88 3651.53 3542.53 1673.83 -3392:46 5947261.27 555316.52 MWD+IFR-AK-CAZ-SC 7977.30 86.39 8.59 3653.34 3544.34 1710.60 -3386.48 5947298.08 555322.22 MWD+IFR-AK-CAZ-SC 8012.87 86.33 8.45 3655.60 3546.60 1745.71 -3381.23 5947333.22 555327.20 .MWD+IFR-AK-CAZ-SC 8038.91 86.83 7.78 3657.15 3548.15 1771.44 -3377.56 5947358.98 555330.67 MWD+IFR-AK-CAZ-SC 8139.31 92.23 5.30 3657.98 3548.98 1871.14 -3366.13 5947458.76 555341.32 MWD+IFR-AK-CAZ-SC 8236.18 91.76 5.59 3654.60 3545.60 1967.51 -3356.94 5947555.19 555349.75 MWD+IFR-AK-CAZ-SC 8330.00 90.09 3.56 3653.09 3544.09 2061.02 -3349.46 5947648.74 555356.50 MWD+IFR-AK-CAZ-SC 8427.50 89.04 3.70 3653.83 3544.83 2158.32 -3343.29 5947746.07 555361.92 MWD+IFR-AK-CAZ-SC 8524.65 90.23 9.76 3654.45 3545.45 2254.75 -3331.91 5947842.58 555372.54 MWD+IFR-AK-CAZ-SC 8622.40 91.27 11.40 3653.17 3544.17 2350.82 -3313.96 5947938.78 555389.74 MWD+IFR-AK-CAZ-SC 8718.63 90.46 9.83 3651.72 3542.72 2445.39 -3296.24 5948033.48 555406.72 MWD+IFR-AK-CAZ-SC i 8815.42 90.47 4.75 3650.93 3541.93 2541.36 -3283.96 5948129.54 555418.25 MWD+IFR-AK-CAZ-SC 8912.71 89.78 359.48 3650.72 3541.72 2638.55 -3280.37 5948226.74 555421.08 MWD+IFR-AK-CAZ-SC 9009.51 89.42 356.62 3651.39 3542.39 2735.28 -3283.67 5948323.43 555417.03 MWD+IFR-AK-CAZ-SC 9106.36 90.16 357.78 3651.75 3542.75 2832.02 -3288.40 5948420.12 555411.55 MWD+IFR-AK-CAZ-SC 9202.72 89.03 358.90 3652.43 3543.43 2928.33 -3291.19 5948516.40 555408.00 MWD+IFR-AK-CAZ-SC 9299.81 89.24 359.61 3653.90 3544.90 3025.40 -3292.45 5948613.44 555405.99 MWD+IFR-AK-CAZ-SC 9396.43 90.47 358.91 3654.14 3545.14 3122.01 -3293.70 5948710.03 555403.98 MWD+IFR-AK-CAZ-SC 9492.28 90.03 357.60 3653.72 3544.72 3217.81 -3296.62 5948805.80 555400.32 MWD+iFR-AK-CAZ-SC 9588.87 91.34 356.95 3652.57 3543.57 3314.28 -3301.21 5948902.22 555394.98 MWD+IFR-AK-CAZ-SC 9685.73 90.77 356.51 3650.78 3541.78 3410.97 -3306.73 5948998.85 555388.70 MWD+IFR-AK-CAZ-SC 9782.15 89.78 357.98 3650.32 3541.32 3507.27 -3311.37 5949095.11 555383.31 MWD+IFR-AK-CAZ-SC 9878.85 90.47 358.91 3650.11 3541.11. 3603.93 -3313.99 5949191.74 555379.94 MWD+IFR-AK-CAZ-SC 9975.86 90.34 0.11 3649.42 3540.42 3700.94 -3314.82 5949288.72 555378.35 MWD+IFR-AK-CAZ-SC 10070.94 90.78 359.88 3648.49 3539.49 3796.01 -3314.83 5949383.78 555377.60 MWD+IFR-AK-CAZ-SC 10167.68 90.78 359.86 3647.18 3538.18 3892.74 -3315.05 5949480.50 555376.63 MWD+IFR-AK-CAZ-SC ~ 10264.50 90.22 359.58 3646.33 3537.33 3989.56 -3315.52 5949577.30 555375.40 MWD+IFR-AK-CAZ-SC 10360.95 90.41 359.52 3645.80 3536.80 4086.00 -3316.28 5949673.73 555373.89 MWD+IFR-AK-CAZ-SC 10459.27 88.98 359.30 3646.33 3537.33 4184.31 -3317.29 5949772.02 555372.11 MWD+IFR-AK-CAZ-SC 10556..33 91.28 358.10 3646.11 3537.11 4281.34 -3319.49 5949869.01 555369.15 MWD+IFR-AK-CAZ-SC 10653.60 90.15 357.32 3644.89 3535.89 4378.52 -3323.38 5949966.15 555364.51 MWD+IFR-AK-CAZ-SC 10749.90 86.62 356.85 3647.61 3538.61 4474.64 -3328.27 5950062.23 555358.87 MWD+IFR-AK-CAZ-SC 10844.14 89.50 356.83 3650.80 3541.80 4568.68 -3333.46 5950156.21 555352.94 MWD+IFR-AK-CAZ-SC 10941..21 89.48 358.45 3651.66 3542.66 4665.66 -3337.46 5950253.14 555348.19 MWD+IFR-AK-CAZ-SC 11039.76 88.74 359.82 3653.19 3544.19 4764.18 -3338.95 5950351.64 555345.93 MWD+IFR-AK-CAZ-SC 11133.51 88.18 358.89 3655.71 3546.71 4857.89 -3340.00 5950445.33 555344.15 MWD+IFR-AK-CAZ-SC 11226,90 90.29 358.58 3656.96 3547.96 4951.24 -3342.07 5950538.66 555341.36 MWD+IFR-AK-CAZ-SC 11280.00 90.43 358.43 3656.62 3547.62 5004.32 -3343.45 5950591.72 555339.56 MWD+IFR-AK-CAZ-SC 11320.72 88.97 358.70 3656.84 3547.84 5045.03 -3344.47 5950632.41 555338.22 MWD+IFR-AK-CAZ-SC 11413.31 88.61 356.45 3658.79 3549.79 5137.51 -3348.39 5950724.85 555333.59 MWD+IFR-AK-CAZ-SC 11507.80 88.37 356.05 3661.28 3552.28 5231.77 -3354.56 5950819.05 555326.67 -MWD+IFR-AK-CAZ-SC 11601.22 88.68 358.17 3663.69 3554.69 5325.03 -3359.27 5950912.26 555321.24 MWD+IFR-AK-CAZ-SC 11692.49 89.05 358.94 3665.49 3556.49 5416.25 -3361.57 5951003.45 555318.23 MWD+IFR-AK-CAZ-SC 11785.73 88.80 359.76 3667.24 3558.24 5509.47 -3362.63 5951096.65 555316.44 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~omp:ui~: ConoroPhillips Alaska Inc. I)aic : 7!1~i20p6 liun ~: 09:27.10 Pa~c: 1 Ficlil: Ku paruk Riv er Unit C~~-~u ~dinai~c(~I.) Rclcrcncr. Well: 1J-170. T rue North tiilr: Kuparuk 1J Pad ~cr~i cnl (I ~l)I Re ference: iJ-1 ~ 0 ~ 109.0 \~cll: 1 J-170 ~ccti un I~~) Refcr cncr. Well i0 00N 0 0 0E0 00Azi) ~1 clllrith: 1 J-170 dun c}~ (alculaliiu i ~lethoil: Minimum Curva ture Ub: Oracle ~unr~ ill) Intl Mini l ~~I) yes l ~I) \r~ F,~~~ ~InpA ~In~il: l~~wl ft deg deg ft ft ft ft ft ft 11889.21 88.49 1.11 3669.69 3560.69 5612.91 -3361.85 5951200.09 555316.42 MWD+IFR-AK-CAZ-SC 11971.72 89.18 1.27 3671.37 3562.37 5695.39 -3360.13 5951282.57 555317.49 MWD+IFR-AK-CAZ-SC 12061.77 88.43 358.71 3673.25 3564.25 5785.41 -3360.15 5951372.58 555316.77 MWD+IFR-AK-CAZ-SC 12152.00 85.70 354.71 3677.87 3568.87 5875.35 -3365.31 5951462.46 555310.91 MWD+IFR-AK-CAZ-SC 12242.78 84.84 356.99 3685.36 3576.36 5965.57 -3371.86 5951552.63 555303.66 MWD+IFR-AK-CAZ-SC 12334.00 85.78 357.12. 3692.81 3583.81 6056.37 -3376.53 5951643.37 555298.28 MWD+IFR-AK-CAZ-SC 12425.27 86.52 357:60 3698.94 3589.94 6147:33 -3380.73 5951734.30 555293.38 MWD+IFR-AK-CAZ-SC 12444.74 87.21 358.00 3700.01 3591.01 6166.76 -3381.47 5951753.71 555292.48 MWD+IFR-AK-CAZ-SC 12479.00 87.21 358.00 .3701.67 - 3592.67 6200.96 -3382.67 5951787.90 555291.02 ° PROJECTED to TD Halliburton Company Survey Report C~nn~einc: ConocoPhillipsAlashe Ir~c. I)atc: 7:1312006 lime : 08.4916 L'a:;c: 1 1 iel~l: Kuparuk River Unit ( ~~~-nrdinak~(\1~:) 12efercncr. Well: 1J-1 r0 T rue North ~itc: K~paruh 1J Pad ~ 'crfic;~l(llI)) K rli~rcucc: iJ-1~OPB1 109.0 ~~cll: 1 J-1'0 ti ccliuu ~~51 Itcfc rcncc_ VJell i0 00N,0.0 0E0 00Azi1 ~1ell~~:uh: 1J-170PE1 S urrey ('alcul:~tiu n ~lcihud: Minimum Curvature Ilb: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate Syste m 1927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bg gm2005 Well: 1 J-170 Slot Name: WeII Position: +N/-S -305.03 ft Northing: 59456 14.10 ft Latitude: 70 15 43.258 N +E/-W -70.73 ft Easti ng : 558721.61 ft Longitude: 149 31 31.065 W Position Un certainty: 0.00 ft Wellpath: 1J-170P61 Drilled From: Well Ref. Point 500292331070 Tie-on Depth: 28.00 ft Current Da tum: 1J-170PB1 : Height 109.00 ft .Above System Datum: Mean Sea Level Magnetic Data: 5/23/2006 Declination: 24.08 deg Field Strength: 57565 nT Mag Dip Ang le: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 6/8/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Na me ft ft 50.00 732.00 1J-170PB 1 gyro (50 .00-732.00) CB-GYRO-SS Camera based gyro single shot 803.23 9246.96 1J-170PB 1 (803.23- 9246.96) MWD+IFR-AK-CAZ-SC MWD+I FR AK CAZ SCC Survey )II1 Jncl ~ciw l'~U Sys"I~Vll \%,ti t:!'~1 ~laiiA ~la~il~ font ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945614.10. 558721.61 TIE LINE 50.00 0.25 25.67 50.00 -59.00 0.04 0.02 5945614.14 558721.63 CB-GYRO-SS 100.00 0.25 22.52 100.00 -9.00 0.24 0.11 5945614.34 558721.72 CB-GYRO-SS 172.00 0.58 33.07 172.00 63.00 0.69 0.37 5945614.80 558721.97 CB-GYRO-SS 267.00 0.88 313.81 266.99 157.99 1.60 0.10 5945615.70 558721.70 CB-GYRO-SS 358.00 3.08 287.40 357.93 248.93 2.82 -2.73 5945616.89 558718.86 CB-GYRO-SS 450.00 5.60 270.56 449.67 340.67 3.60 -9.58 5945617.62 558712.00 CB-GYRO-SS 540.00 7.50 260.08 539.08 430.08 2.63 -19.76 5945616.58 558701.83 CB-GYRO-SS 632.00 9.14 250.71 630.11 521.11 -0.82 -32.57 5945613.03 558689.05 CB-GYRO-SS 732.00 12.79 234.79 728.29 619.29 -9.83 -49.12 5945603.89 558672.57 CB-GYRO-SS 803.23 14.79 229.29 797.47 688.47 -20.31 -62.46 5945593.31 558659.32 MWD+IFR-AK-CAZ-SC 857.48 15.67 226.57 849.81 740.81 -29.86 -73.03 5945583.67 558648.83 MWD+IFR-AK-CAZ-SC 948.06 20.33 228.41 935.93 826.93 -48.73 -93.69 5945564.65 558628.31 MWD+IFR-AK-CAZ-SC 1041.06 24.31 230.15 1021.95 912.95 -71.72 -120.48 5945541.44 558601.70 MWD+IFR-AK-CAZ-SC 1134.20 28.34 230.76 1105.41. 996.41 -98.00 -152.33 5945514.92 558570.06 MWD+IFR-AK-CAZ-SC 1225.44 33.10 230.11 1183.83 1074.83 -127.70 -188.24 5945484.95 558534.39 MWD+IFR-AK-CAZ-SC 1318.35 37.47 231.40 1259.65 1150.65 -161.62 -229.82 5945450.71 558493.08 MWD+IFR-AK-CAZ-SC 1410.82 40.50 233.18 1331.52 1222.52 -197.17 -275.85 5945414.81 558447.34 MWD+IFR-AK-CAZ-SC 1504.40 42.52 233.73 1401.60 1292.60 -234.09 -325.67 5945377.50 558397.80 MWD+IFR-AK-CAZ-SC 1596.02 46.06 233.75 1467.17 1358.17 -271.92 -377.25 5945339.27 558346.53 MWD+IFR-AK-CAZ-SC 1689.22 45.31 233.86 1532.28 1423.28 -311.30 -431.07 5945299.47 558293.02 MWD+IFR-AK-CAZ-SC 1782.35 50.09 232.99 1594.94 1485.94 -352.35 -486.36 5945258.00 558238.06 MWD+IFR-AK-CAZ-SC 1873.86 55.20 232.89 1650.44 1541.44 -396.18 -544.38 5945213.73 558180.38 MWD+IFR-AK-CAZ-SC 1966.96 58.05 234.02 1701.66 1592.66 -442.46 -606.84 5945166.97 558118.29 MWD+IFR-AK-CAZ-SC 2061.56 61.81 234.48 1749.05 1640.05 -490.27 -673.28 5945118.64 558052.24 MWD+IFR-AK-CAZ-SC 2153.34 66.94 235.16 1788.73 1679.73 -537.93 -740.90 5945070.46 557985.00 MWD+IFR-AK-CAZ-SC 2245.85 68.35 235.35 1823.91 1714.91 -586.69 -811.20 5945021.16 557915.09 MWD+IFR-AK-CAZ-SC 2340.01 . 66.55 234.38 1860.02 1751.02 -636.73 -882.31 5944970.57. 557844.37 MWD+IFR-AK-CAZ-SC 2430.35 66.09 233.38 1896.31 1787.31 -685.49 -949.14 5944921.29 557777.93 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ('onipam: ConocoPhillipsAlaska Inc_ Daic: 7; 1~r~006 liuic: 05.49:16 Pa,r._ I~iclil: Kuparuk P,iver Unit (~u-nnlin:rtrlA1') Kcferencc: Well: 1J-170. True North ~tii~c: Kuparuk 1J Pad ~~crlical (Ill)1 Kcli~rcnec: 1J-170P61 109.0 ~~cll: 1J-170 ~ectiuu f~~Sl Kcferencc: Well i0.OON,O-OOEO OOAziI \1cll~~a[h: 1 J-170P61 Sure c~ f alrulali~m \Icthu~l: Minimum Curvature I)h: Oracle ~unc~ ~H) Incl \iim l~ l) acs l~ U \/ti I~;'11 11a~i,A \lapl_ Inul ft deg deg ft ft ft ft ft ft 2524.20 66.73 232.33 1933.86 1824.86 -737.43 -1017.70 5944868.83 557709.79 MWD+IFR-AK-CAZ-SC I 2617.29 65.63 232.42 1971.46 1862.46 -789.42 -1085.15 5944816.32 557642.76 MWD+IFR-AK-CAZ-SC 2708.83 65.47 232.71 2009.35 1900.35 -840.07 -1151.32 5944765.16 557576.99 MWD+IFR-AK-CAZ-SC 2801.61 66.32 234.48 2047.24 1938.24 -890.33 -1219.48 5944714.38 557509.23 MWD+IFR-AK-CAZ-SC 2893.74 64.53 235.05 2085.56 1976.56 -938.66 -1287.90 5944665.51 557441.19 MWD+IFR-AK-CAZ-SC 2988.02 66.31 235.05 2124.77 2015.77 -987.78 -1358.18 5944615.86 557371.31 MWD+IFR-AK-CAZ-SC 3074.18 65.18 236.36 2160.17 2051.17 -1032.04 -1423.07 5944571.09 557306.77 MWD+IFR-AK-CAZ-SC 3105.86 63.95 236.54 2173.77 2064.77 -1047.85 -1446.91 5944555.10 557283.05 MWD+IFR-AK-CAZ-SC 3200.29 64.63 235.81 2214.74 2105.74 -1095.21 -1517.59 5944507.19 557212.75 MWD+IFR-AK-CAZ-SC 3291.60 63.12 238.30 2254.95 2145.95 -1139.80 -1586.37 5944462.07 557144.33 MWD+IFR-AK-CAZ-SC 3384.37 63.59 241.70 2296.56 2187.56 -1181.25 -1658.17 5944420.07 557072.86 MWD+IFR-AK-CAZ-SC .3478.44 63.52 245.56 2338.47 2229.47 -1218.65 -1733.61 5944382.09 556997.72 MWD+IFR-AK-CAZ-SC 3572.09 64.29 249.70 2379.67 2270.67 -1250.64 -1811.37 5944349.50 556920.23 MWD+IFR-AK-CAZ-SC 3666.38 63.60 255.60 2421.12 2312.12 -1275.90 -1892.17 5944323.61 556839.63 MWD+IFR-AK-CAZ-SC 3761.00 63.46 260.73 2463.32 2354.32 -1293.26 -1975.03 5944305.60 556756.92 MWD+IFR-AK-CAZ-SC 3853.11 64.39 266.07 2503.83 2394.83 -1302.75 -2057.17 5944295.47 556674.86 MWD+IFR-AK-CAZ-SC 3946.84 67.20 273.93 2542.30 2433.30 -1302.69 -2142.56 5944294.87 .556589.48 MWD+IFR-AK-CAZ-SC 4039.97 65.00 278.25 2580.05 2471.05 -1293.68 -2227.20 5944303.21 556504.78 MWD+IFR-AK-CAZ-SC 4133.23 64.70 281.87 2619.69 2510.69 -1278.94 -2310.30 5944317.30 556421.57 MWD+IFR-AK-CAZ-SC 4224.53 63.44 282.61 2659.61 2550.61 -1261.54 -2390:54 5944334.08 556341.21 MWD+IFR-AK-CAZ-SC 4319.36 66.10 283.59 2700.03 2591.03 -1242.09 -2474.08 5944352.87 556257.53 MWD+IFR-AK-CAZ-SC 4412.60 66.79 282.94 2737.29 2628.29 -1222.48 -2557.27 5944371.83 556174.19 MWD+IFR-AK-CAZ-SC 4505.54 67.18 282.40 2773.63 2664.63 -1203.72 -2640.73 5944389.94 556090.60 MWD+IFR-AK-CAZ-SC 4601.05 67.18 284.97 2810.68 2701.68 -1182.89 -2726.26 5944410.10 556004.92 MWD+IFR-AK-CAZ-SC 4690.50 66.73 288.90 2845.71 2736.71 -1158.93 -2804.98 5944433.45 555926.02 MWD+IFR-AK-CAZ-SC 4780.83 65.35 293.36 2882.40 2773.40 -1129.20 -2881.95 5944462.57 555848.83 MWD+IFR-AK-CAZ-SC 4879.54 64.12 298.89 2924.56 2815.56 -1089.93 -2962,07 5944501.21 555768.42 MWD+IFR-AK-CAZ-SC 4972.71 63.90 302.49 2965.40 2856.40 -1047.20 -3034.07 5944543.37 555696.09 MWD+IFR-AK-CAZ-SC 5068.22 64.61 306.75 3006.90 2897.90 -998.33 -3104,84 5944591.68 555624.95 MWD+IFR-AK-CAZ-SC 5160.02 64.66 312.00 3046.25 2937.25 -945.73 -3168.93 5944643.78 555560.46 MWD+IFR-AK-CAZ-SC 5254.34 67.22 318.22 3084.73 2975.73 -884.73 -3229.63 5944704.30 555499.28 MWD+IFR-AK-CAZ-SC 5345.64 67.73 323.79 3119.73 3010.73 -819.21 -3282.67 5944769.39 555445.74 MWD+IFR-AK-CAZ-SC 5438.98 67.21 329.57 3155.52 3046.52 -747.21 -3330.01 5944841.02 555397.85 MWD+IFR-AK-CAZ-SC 5533.31 68.47 335.37 3191.13 3082.13 -669.78 -3370.35 5944918.13 555356.91 MWD+IFR-AK-CAZ-SC 5625.93 72.12 341.26 3222.37 3113.37 -588.79 -3402.50 5944998.85 555324.13 MWD+IFR-AK-CAZ-SC 5719.45 72.25 346.61 3251.01 3142.01 -503.27 -3427.12 5945084.17 555298.84 MWD+IFR-AK-CAZ-SC 5814.69 73.89 352.76 3278.76 3169.76 -413.68 -3443.41 5945173.62 555281.86 MWD+IFR-AK-CAZ-SC 5907.49 75.91 358.77 3302.96 3193.96 -324.38 -3450.00 5945262.86 555274.58 MWD+IFR-AK-CAZ-SC 6000.27 78.27 359.79 3323.69 3214.69 -233.96 -3451.13 5945353.26 555272.74 MWD+IFR-AK-CAZ-SC 6093.70 78.76 359.45 3342.29 3233.29 -142.40 -3451.74 5945444.80 555271.42 MWD+IFR-AK-CAZ-SC 6186.46 79.63 358.81 3359.68 3250.68 -51.30 -3453.12 5945535.88 555269.32 MWD+IFR-AK-CAZ-SC 6280.24 78.96 357.80 3377.10 3268.10 40.81 -3455.85 5945627.96 555265.88 MWD+IFR-AK-CAZ-SC 6371.85 79.47 357.84 3394,24 3285.24 130.74 -3459.27 5945717.84 555261.76 MWD+IFR-AK-CAZ-SC 6466.74 78.89 358.55 3412.05 3303.05 223.89 -3462.21 5945810.97 555258.09 MWD+IFR-AK-CAZ-SC 6558.69 79.15 0.20 3429.57 3320.57 314.15 -3463.19 5945901.20 555256.41 MWD+IFR-AK-CAZ-SC 6654.07 79:53 0.30. 3447.21 3338.21 407.88 -3462.78 5945994.93 555256.09 .MWD+IFR-AK-CAZ-SC .6748.08 79.92 1.52 3463.98 3354.98 500.37 -3461.31 5946087.42 555256.83 MWD+IFR-AK-CAZ-SC 6839.78 79.97 2.18 3479.99 3370.99 590.61 -3458.40 5946177.67 555259.04 MWD+IFR-AK-CAZ-SC 6932.31 77.70 1.79 3497.91 3388.91 681.33 -3455.25 5946268.40 555261.48 MWD+IFR-AK-CAZ-SC 7026.06 80.25 2.03 3515.83 3406.83 773.29 -3452.18 5946360.38 555263.83 MWD+IFR-AK-CAZ-SC 7120.19 81.46 1.85 3530.79 3421.79 866.17 -3449.04 5946453.27 555266.25 MWD+IFR-AK-CAZ-SC 7212.95 80.71 1.51 3545.17 3436.17 957.77 -3446.35 5946544.88 555268.23 MWD+IFR-AK-CAZ-SC I Halliburton Company Survey Report (iuut~au~: ConocoPhillipsAlasha Inc. Ilatc : r/13i2C06 Iinu ~: 084910 1'n_c: 3 1 icl~l: Kup2ruk Riv er Unit (~~~-~ udinalc~A I.) Rcli~rcncc: Well_ 1J-1 r0, T rue North Sitc: Kupanik 1J P2d ~cr~ icail f Ill)t Kcfcrcncc: 1J-170PE31 109.0 ~1i~11: 1J-17U Secti on I~~SI It cfcrrncc W211 i0 00N 0 O OE.U OOA~iI 11cllpath: 1 J-170P61 Sun g (ulcula tiun ~lciho~l: Minimum Curva ture I)h: Oracle ~urccc III) Intl Mini fill S~~lll) AiS 1:1~ 11apA ~LitiF: l~~i~~l ft deg ieq ft tt ft ft ft ft 7308.21 81.13 1.24 3560.20 3451.20 1051.81 -3444.10 5946638.92 555269.75 MWD+IFR-AK-CAZ-SC 7399.75 81.48 2.49 3574.04 3465.04 1142.25 -3441.15 5946729.37 555271.99 MWD+IFR-AK-CAZ-SC 7492.77 79.85 4.14 3589.13 3480.13 1233.88 -3435.85 5946821.03 555276.58 MWD+IFR-AK-CAZ-SC 7587.32 79.37 4.72 3606.18 3497.18 1326.60 -3428.66 .5946913.79 555283.04 MWD+IFR-AK-CAZ-SC 7680.09 80.34 5.23 3622.52 3513.52 1417.57 -3420.74 5947004.82 555290.25 MWD+IFR-AK-CAZ-SC 7772.11 80.45 .4.38 3637.88 3528.88 1507.98 -3413.14 5947095.28 555297.14 MWD+IFR-AK-CAZ-SC 7859.80 86.59 7.19 3647.77 3538.77 1594.62 -3404.35 5947181.97 555305.25 MWD+IFR-AK-CAZ-SC 7944.93 88.13 10.05 3651.69 3542.69 1678.68 -3391.61 5947266.12 555317.34 MWD+IFR-AK-CAZ-SC 8041.57 89.55 9.90 3653.65 3544.65 1773.84 -3374.87 5947361.40 555333.33 MWD+IFR-AK-CAZ-SC 8137.46 86.63 10.47 3656.84 3547.84 1868.16 -3357.93 5947455.84 555349.54. MWD+IFR-AK-CAZ-SC 8234.54 85.22 10.83 3663.74. 3554.74 1963.32 -3340.03 5947551.13 555366.69 .MWD+IFR-AK-CAZ-SC 8332.26 87.83 12.71 3669.67 3560.67 2058.80 -3320.14 5947646.75 555385.84 MWD+IFR-AK-CAZ-SC 8427.97 84.88 8.94 3675.75 3566,75 2152.59 -3302.20 5947740.66 555403.05 MWD+IFR-AK-CAZ-SC 8526.45 86.28 6.90 3683.34 3574.34 2249.83 -3288.67 5947838.00 555415.81 MWD+IFR-AK-CAZ-SC ' 8622.23 90.86 5.01 3685.73 3576.73 2345.03 -3278.74 5947933.27 555425.00 MWD+IFR-AK-CAZ-SC 8717.95 92.02 2.99 3683.33 3574.33 2440.48 -3272.07 5948028.76 555430.93 MWD+IFR-AK-CAZ-SC 8814.07 92.20 359.98 3679.79 3570.79 2536.49 -3269.58 5948124.78 555432.67 MWD+IFR-AK-CAZ-SC 8911.39 93.01 358.90 .3675.36 3566.36 2633.71 -3270.53 5948221.97 555430.96 MWD+IFR-AK-CAZ-SC 9008.35 93.68 358.47 3669.71 3560.71 2730.48 -3272.75 5948318.71 555427.98 MWD+IFR-AK-CAZ-SC 9105.74 97.06 358.64 3660.59 3551.59 2827.39 -3275.19 5948415.60 555424.78 MWD+IFR-AK-CAZ-SC 9201.74 99.48 359.03 3646.79 3537.79 2922.37 -3277.13 5948510.54 555422.11 .MWD+IFR-AK-CAZ-SC 9246.96 99.41 358.46 3639.37 3530.37 2966.96 -3278.10 5948555.13 555420.79 MWD+IFR-AK-CAZ-SC 9281.00 99.41 358.46 3633.80 3524.80 3000.53 -3279.01 5948588.69. 555419.62 PROJECTED to TD • Halliburton Company Survey Report ('nm~r~uc: ConocoP9111ipsAlaska Inc. U:uc: 7/13!20D6 liwc: 09:9t17 Pa~c: l I~iclil: Kuparuk Ri~~er Unit ( u-u rdinatc(\F) Rcli~rcncr. Well: 1J-1 ~D, T rue Nn~h tii(c: Kuparuk 1J Pad V ~crtic:~l (f~11~ Kcfcrcncc: 1J-170P62 10 9.0 ~~cll: 1J-1 i0 ti cciiun ~~5) Rcfcrcncr. Well i0.OON,O O OEO-OCA~iI 1lrllpath: 1J-170PB2 ~ unc}(~slculatiun~Icthocl: tv9inin'~arnCurvature I)h: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 J-170 Slot Name: Well Position: +N/-S -305.03 ft Northing: 5945614.10 ft Latitude: 70 15 43.258 N +E/-W -70.73 ft Easting : 558 721.61 ft Longitude: 149 31 31.065 W Position Uncertainty: 0.00 ft Wellpath: 1J-170PB2 Drilled From: 1J-170PB1 500292331071 Tie-on Depth: 7859.80 ft Current Datum: 1J-170PB2: Height, 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/23/2006 Declination: 24.08 deg Field Strength: .57565 nT Mag Dip Angle: 80.77 deg Vertical Sec tion: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28:00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 7/13/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 732.00 1J-170PB1 gyro (50 .00-732.00) CB-GYRO-SS Camera based gyro single shot 803.23 7859.80 1 J-170PB1 (803.23-9246.96) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7940.00 11881.26 1 J-170PB2 (7940.00-11881.26) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey SID Intl r~iiin ~II~D Sti~s~Il~D \S I.-l~ ~la~iA ~lapF; lunl ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945614.10 558721.61 TIE LINE 50.00 0.25 25.67 50.00 -59.00 0.04 0.02 5945614.14 558721:63 CB-GYRO-SS 100.00 0.25 22.52 100.00 -9.00 0.24 0.11 5945614.34 558721.72 CB-GYRO-SS 172.00 0.58 33.07 172.00 63.00 0.69 0.37 5945614.80 558721.97 CB-GYRO-SS 267.00 0.88 313.81 266.99 157.99 1.60 0.10 .5945615.70 558721.70 CB-GYRO-SS ~ 358.00 3.08 287.40 357.93 248.93 2.82 -2.73 5945616.89 558718.86 CB-GYRO-SS 450.00 5.60 270.56 449.67 340.67 3.60 -9.58 5945617.62 558712.00 CB-GYRO-SS 540.00 7.50 260.08 539.08 430.08 2.63 -19.76 5945616.58 558701.83 CB-GYRO-SS 632.00 9.14 250.71 630.11 521.11 -0.82 -32.57 5945613.03 558689.05 CB-GYRO-SS 732.00 12.79 234.79 728.29 619.29 -9.83 -49.12 5945603.89 558672.57 CB-GYRO-SS 803.23 14.79 229.29 797.47 688.47 -20.31 -62.46 5945593.31 .558659.32 MWD+IFR-AK-CAZ-SC 857.48 15.67 226.57 849.81 740.81 -29.86 -73.03 5945583.67 558648.83 MWD+IFR-AK-CAZ-SC 948.06 20.33 228.41 935.93 826.93 -48.73 -93.69 5945564.65 558628.31 MWD+IFR-AK-CAZ-SC 1041.06 24.31 230.15 1021.95 912.95 -71.72 -120.48 5945541.44 558601.70 MWD+IFR-AK-CAZ-SC 1134.20 28.34 230.76 1105.41 996.41 -98.00 -152.33 5945514.92 558570.06 MWD+IFR-AK-CAZ-SC 1225.44 33.10 230.11 1183.83 1074.83 -127.70 -188.24 5945484.95 558534.39 MWD+IFR-AK-CAZ-SC 1318.35 37.47 231.40 1259.65 1150.65 -161.62 -229.82 5945450.71 558493.08 MWD+IFR-AK-CAZ-SC 1410.82 40.50 233.18 1331.52 1222.52 -197.1.7 -275.85 5945414.81 558447.34 MWD+IFR-AK-CAZ-SC 1504.40 42.52 233.73 1401.60 1292.60 -234.09 -325.67 5945377.50 558397.80 MWD+IFR-AK-CAZ-SC 1596.02 46.06 233.75 1467.17 1358.17 -271.92 -377.25 5945339.27 558346.53 MWD+IFR-AK-CAZ-SC 1689.22 45.31 233.86 1532.28 1423.28 -311.30 -431.07 5945299.47 558293.02 MWD+fFR-AK-CAZ-SC 1782.35 50.09 232.99 1594.94 1485.94 -352.35 -486.36 5945258.00 558238.06 MWD+IFR-AK-CAZ-SC 1873.86 55.20 232.89 1650.44 1541.44 -396.18 -544.38 5945213.73 558180.38 MWD+IFR-AK-CAZ-SC 1966.96 58.05 234.02 1701.66 1592.66 -442.46 -606.84 5945166.97 558118.29 MWD+IFR-AK-CAZ-SC ~ 2061.56 61.81 234.48 1749.05 1640.05 -490.27 -673.28 5945118:64 558052.24 MWD+IFR-AK-CAZ-SC 2153.34 66.94 235.16 1788.73 1679.73 -537.93 -740.90 5945070.46 557985.00 MWD+IFR-AK-CAZ-SC j 2245.85 68.35 235.35 1823.91 1714.91 -586.69 -811.20 5945021.16 557915.09 MWD+IFR-AK-CAZ-SC 2340.01 66.55 234.38 1860.02 1751.02 -636.73 -882.31 5944970.57 557844.37 . MWD+IFR-AK-CAZ-SC ~ Halliburton Company Survey Report ('~nup:~u}: ConoroPhillipsAlask~ Inc. Dafr i;1~1~006 Iinic: 09:01:17 P,ic: 1 iclil: Kuparuk River Unit (~~~-urdinarelAl:1 I:efcrcncc: Well: ~iJ-1 ~ 0, True North ~~i1e•: K~~iparuk 1J Pad ~crtical ~llll) Reference: 1J-170PB2 109-0 ~~cll: 1 J-170 ~ecliuu (~S) Rcfercucc: Well l0 00N 0 00E,0 00A~i'~ ~1cllpnth: 1J-170PB2 ~nn~c~ (alculaLion ~1cLhuil: fvlinimurn CurvatUrE Uh: Oracl° tiur~ r~ X11) ]ncl ~cim l~ U S_„ l I'll V',ti F: ~~ ~IspA ~1a~il: foul ft deg deg ft ft ft ft ft ft 2430.35 66.09 233.38 1896.31 1787.31 -685.49 -949.14 5944921.29 557777.93 MWD+IFR-AK-CAZ-SC ~ 2524.20 66.73 232.33 1933.86 1824.86 -737.43 -1017.70 5944868.83 557709.79 MWD+IFR-AK-CAZ-SC 2617.29 65.63 232.42 1971.46 1862.46 -789.42 -1085.15 5944816.32 557642.76 MWD+IFR-AK-CAZ-SC 2708.83 65.47 232.71 2009.35 1900.35 -840.07 -1151.32 5944765.16 557576.99 MWD+IFR-AK-CAZ-SC 2801.61 66.32 234.48 2047.24 1938.24 -890.33 -1219.48 5944714.38 557509.23 MWD+IFR-AK-CAZ-SC 2893.74 64.53 235.05 2085.56 1976.56 -938.66 -1287.90 5944665.51 557441.19 MWD+IFR-AK-CAZ-SC 2988.02 66.31 235.05 2124.77 2015.77 -987.78 -1358.18 5944615.86 557371.31 MWD+IFR-AK-CAZ-SC 3074.18 65.18 236.36 2160.17 2051.17 -1032.04 -1423.07 5944571.09 557306.77 MWD+IFR-AK-CAZ-SC 3105.86 63.95 236.54 2173.77 2064.77 -1047.85 -1446.91 5944555.10 557283.05 MWD+IFR-AK-CAZ-SC 3200.29 64.63 235.81 2214.74 2105.74 -1095.21 -1517.59 5944507.19 557212.75 MWD+IFR-AK-CAZ-SC 3291.60 63.12 238.30 2254.95 2145.95 -1139:80 -1586.37 5944462.07 557144.33 MWD+IFR-AK-CAZ-SC 3384.37 63.59 241.70 2296.56 2187.56 -1181.25 -1658.17 5944420.07 557072.86 MWD+IFR-AK-CAZ-SC 3478.44 63.52 245.56 2338.47 2229.47 -1218.65 -1733.61 5944382.09 556997.72 MWD+IFR-AK-CAZ-SC 3572.09 64.29 249.70 2379.67 2270.67 -1250.64 -1811.37 5944349.50 556920.23 MWD+IFR-AK-CAZ-SC 3666.38 63.60 255.60 2421.12 2312.12 -1275.90 -1892.,17 5944323.61 556839.63 MWD+IFR-AK-CAZ-SC 3761.00 63.46 260.73 2463.32 2354.32 -1293.26 -1975.03 5944305.60 556756.92 MWD+IFR-AK-CAZ-SC 3853.11 64.39 266.07 2503.83 2394.83 -1302.75 -2057.17 5944295.47 556674.86 MWD+IFR-AK-CAZ-SC 3946.84 67.20 273.93 2542.30 2433.30 -1302.69 -2142.56 5944294.87 556589.48 MWD+IFR-AK-CAZ-SC 4039.97 65.00 278.25 2580.05 2471.05 -1293.68 -2227.20 5944303.21 556504.78 MWD+IFR-AK-CAZ-SC 4133.23 64.70 281.87 2619.69 2510.69 -1278.94 -2310.30 5944317.30 556421.57 MWD+IFR-AK-CAZ-SC 4224.53 63.44 282.61 2659.61 2550.61 -1261.54 -2390.54 5944334.08 556341.21 MWD+IFR-AK-CAZ-SC 4319.36 66.10 283.59 2700.03 2591.03 -1242.09 -2474.08 5944352.87 556257.53 .MWD+IFR-AK-CAZ-SC 4412.60 66.79 282.94 2737.29 2628.29 -1222.48 -2557.27 5944371.83 556174.19 MWD+IFR-AK-CAZ-SC 4505.54 67.18 282.40 2773.63 2664.63 -1203.72 -2640.73 5944389.94 556090.60 MWD+IFR-AK-CAZ-SC 4601.05 67.18 284.97 2810.68 2701.68 -1182.89 -2726.26 5944410.10 556004.92 MWD+IFR-AK-CAZ-SC 4690.50 66.73 288.90 2845.71 2736.71 -1158.93 -2804.98 5944433.45 555926.02 :MWD+IFR-AK-CAZ-SC 4780.83 65.35 293.36. 2882.40 2773.40 -1129.20 -2881.95 5944462.57 555848.83 MWD+IFR-AK-CAZ-SC 4879.54 64.12 298.89 2924.56 2815.56 -1089.93 -2962.07 5944501.21 555768.42 MWD+IFR-AK-CAZ-SC 4972,71 63.90 302.49 2965.40 2856.40 -1047.20 -3034.07 5944543.37 555696.09 MWD+IFR-AK-CAZ-SC 5068.22 64.61 306.75 3006.90 2897.90 -998.33 -3104.84 5944591.68 555624.95 MWD+IFR-AK-CAZ-SC 5160.02 64.66 312.00 3046.25 2937.25 -945.73 -3168.93 5944643.78 555560.46 MWD+IFR-AK-CAZ-SC 5254.34 67.22 318.22 3084.73 2975.73 -884.73 -3229.63 5944704.30 555499.28 MWD+IFR-AK-CAZ-SC 5345.64 67.73 323.79 3119.73 3010.73 -819.21 -3282.67 5944769.39 555445.74 MWD+IFR-AK-CAZ-SC 5438.98 67.21 329.57 3155.52 .3046.52 -747.21 -3330.01 5944841.02 555397.85 MWD+IFR-AK-CAZ-SC 5533.31 68.47 335.37 3191.13 3082.13 -669.78 -3370.35 5944918.13 555356.91 MWD+IFR-AK-CAZ-SC 5625.93 72.12 341.26 3222.37. 3113.37 -588.79 -3402.50 5944998.85 555324.13 MWD+IFR-AK-CAZ-SC 5719.45 72.25 346.61 3251.01 3142.01 -503.27 -3427.12 5945084.17 555298.84 MWD+IFR-AK-CAZ-SC 5814.69 73.89 352.76 3278.76 3169.76 -413.68 -3443.41 5945173.62 555281.86 MWD+IFR-AK-CAZ-SC 5907.49 75.91 358.77 3302.96 3193.96 -324.38 -3450.00 5945262.86 555274.58 MWD+IFR-AK-CAZ-SC 6000.27 78.27 359.79 3323.69 3214.69 -233.96 -3451.13 5945353.26 555272.74 MWD+IFR-AK-CAZ-SC 6093.70 78.76 359.45 3342.29 3233.29 -142.40 -3451.74 5945444.80 555271.42 MWD+IFR-AK-CAZ-SC 6186.46 79.63 358.81 3359.68 3250.68 -51.30 -3453.12 5945535.88 555269.32. MWD+IFR-AK-CAZ-SC 6280.24 78.96 357.80 3377.10 3268.10 40.81 -3455.85 5945627.96 555265.88 MWD+IFR-AK-CAZ-SC 6371.85 79.47 357.84 3394.24 3285.24 130.74 -3459.27 5945717.84 555261.76 MWD+IFR-AK-CAZ-SC 6466.74 78.89 358.55 3412.05 3303.05 223.89 -3462.21 5945810.97 555258.09 MWD+IFR-AK-CAZ-SC 6558.69 79.15 0.20 3429.57 3320.57 314.15 -3463.19 5945901.20 555256.41 MWD+IFR-AK-CAZ-SC 6654.07 79.53 0.30 3447.21 3338.21 407.88 -3462.78 5945994.93. 555256.09 MWD+IFR-AK-CAZ-SC 6748.08 79.92 1.52 3463.98 3354.98 500,37 -3461.31 5946087.42 555256.83 MWD+IFR-AK-CAZ-SC i 6839.78 79.97 2.18 3479.99 3370.99 590.61 -3458.40 5946177.67 555259.04 MWD+IFR-AK-CAZ-SC 6932.31 77.70 1.79 3497.91 3388.91 681.33 -3455.25 5946268.40 555261.48 MWD+IFR-AK-CAZ-SC ~ 7026.06 80.25 2.03 3515.83 3406.83 773.29 -3452.18 5946360.38 555263.83 MWD+IFR-AK-CAZ-SC j 7120.19 81.46 1.85 3530.79 3421.79 866.17 -3449.04 5946453.27 555266.25 MWD+IFR-AK-CAZ-SC I Halliburton Company Survey Report ('~uupau~: ConocoPhillips Alaska Inc. I).uc: r13r2006 7iiuc: 09.01 ~ 17 I'ar. 3 Piel~l: Ku panik River Unit Cu-~~r~linatcl~l.) Rcfcrrncc: Well: 1J-1 ~ 0, Tr~,ie North ~itc: Kuparuk 1J Pad ~crlicnl I Il I)1 Ilcfcrcncc: 1J-17CPB2- 109.0 ~~cll: 1 J-1 ~ 0 ~ectiun f~til Kcfcrencc: Well (O OGN_O OOE 0-OOAzij ~~'cllpath: 1J-170PE2 ~ur~c~ ('alcul:uiun ~lcthixl: Minimum Curvature I)h: Oracle tim~c~ X111 Intl ~cin~ l~~l) ~~tilll) \%,ti I!'\~ )lahA 11spF; inul ft deg deg ft ft ft ft ft ft 7212.95 80.71 1.51 3545.17 3436.17 957.77 -3446.35 5946544.88 555268.23 MWD+IFR-AK-CAZ-SC 7308.21 81.13 1.24 3560.20 3451.20 1051.81 -3444.10 5946638.92 555269.75 MWD+IFR-AK-CAZ-SC 7399.75 81.48 2.49 3574.04 3465.04 1142.25 -3441.15 5946729.37 555271.99 MWD+IFR-AK-CAZ-SC 7492.77 79.85 .4.14 3589.13 3480.13 1233.88 -3435.85 5946821.03 555276.58 MWD+IFR-AK-CAZ-SC 7587.32 79.37 4.72 3606.18 3497.18 1326.60 -3428.66 5946913.79 555283.04 MWD+IFR-AK-CAZ-SC 7680.09 80.34 5.23 3622.52 3513.52 1417.57 -3420.74 5947004.82 555290.25 MWD+IFR-AK-CAZ-SC 7772.11 80.45 4.38 3637.88 3528.88 1507.98 -3413.14 5947095.28 555297.14 MWD+IFR-AK-CAZ-SC 7859.80 86.59 7.19 3647.77 3538.77 1594.62 -3404.35 5947181.97 555305.25 MWD+IFR-AK-CAZ-SC 7940.00 88.04 9.88 3651.53 3542.53 1673.83 -3392.46 5947261.27 555316.52 MWD+IFR-AK-CAZ-SC 7977.30. 86.39 8.59 3653.34 3544.34 1710.60 -3386.48 5947298.08 555322.22 MWD+IFR-AK-CAZ-SC 8012.87 86.33 8.45 3655.60 3546.60 1745.71 -3381.23 5947333.22 555327.20 MWD+IFR-AK-CAZ-SC 8038.91 86.83 7.78 .3657.15 3548.15 1771.44 -3377.56 5947358.98 555330.67 MWD+IFR-AK-CAZ-SC 8139.31 92.23 5.30 3657.98 3548.98 1871.14 -3366.13 5947458.76 555341.32 MWD+IFR-AK-CAZ-SC 8236.18 91.76 5.59 3654.60 3545.60 1967.51 -3356.94 5947555.19 555349.75 .MWD+IFR-AK-CAZ-SC 8330.00 90.09 3.56 3653.09 3544.09 2061.02 -3349.46 5947648.74 555356.50 MWD+IFR-AK-CAZ-SC 8427.50 89.04 3.70 3653.83 3544.83 2158.32 -3343.29 5947746.07 555361.92 MWD+IFR-AK-CAZ-SC 8524.65 90.23 9.76 3654.45 3545.45 2254.75 -3331.91 5947842.58 555372.54 MWD+IFR-AK-CAZ-SC 8622.40 91.27 11.40 3653.17 3544.17 2350.82 -3313.96 5947938.78 555389.74 MWD+IFR-AK-CAZ-SC 8718.63 90.46 9.83 3651.72 3542.72 2445.39 -3296.24 5948033.48 555406.72 MWD+IFR-AK-CAZ-SC 8815.42 90.47 4.75 3650.93 3541.93 2541.36 -3283.96 5948129.54 555418.25 MWD+IFR-AK-CAZ-SC 8912.71 89.78 359.48 3650.72 3541:72 2638.55 -3280.37 5948226.74 555421.08 MWD+IFR-AK-CAZ-SC 9009.51 89.42 356.62 3651.39 3542.39 2735.28 -3283.67 5948323.43 555417.03 MWD+IFR-AK-CAZ-SC 9106.36 90.16 357.78 3651.75 3542.75 2832.02 -3288.40 5948420.12 555411.55 MWD+IFR-AK-CAZ-SC 9202.72 89.03 358.90 3652.43 3543.43 2928.33 -3291.19 5948516.40 555408.00 MWD+IFR-AK-CAZ-SC 9299.81 89.24 359.61 3653.90 3544.90 3025.40 -3292.45 5948613.44 555405.99 MWD+IFR-AK-CAZ-SC 9396.43 90.47 358.91 3654.14 3545.14 3122.01 -3293.70 5948710.03 555403.98 MWD+IFR-AK-CAZ-SC 9492.28 90.03 357.60 3653.72 3544.72 3217.81 -3296.62 5948805.80 555400.32 MWD+IFR-AK-CAZ-SC 9588.87 91.34 356.95 3652.57 3543.57 3314.28 -3301.21 5948902.22 555394.98 MWD+IFR-AK-CAZ-SC 9685.73 90.77 356.51 3650.78 3541.78 3410.97 -3306.73 5948998.85 555388.70 MWD+IFR-AK-CAZ-SC 9782.15 89.78 357.98 3650.32 3541.32 3507.27 -3311.37 5949095.11 555383.31 MWD+IFR-AK-CAZ-SC 9878.85 90.47 358.91 3650.11 3541.11 3603.93 -3313.99 5949191.74 555379.94 MWD+IFR-AK-CAZ-SC 9975.86 90.34 0.11 3649.42 3540.42 3700.94 -3314.82 5949288.72 555378.35 MWD+IFR-AK-CAZ-SC 10070.94 90.78 359.88 3648.49 3539.49 3796.01 -3314.83 5949383.78 555377.60 MWD+IFR-AK-CAZ-SC 10167.68 90.78 359.86 3647.18 3538.18 3892.74 -3315.05 5949480.50 555376.63 MWD+IFR-AK-CAZ-SC 10264.50 90.22 359.58 3646.33 3537.33 3989.56 -3315.52 5949577.30 555375.40 MWD+IFR-AK-CAZ-SC 10360.95 90.41 359.52 3645.80 3536.80 4086.00 -3316.28 5949673.73 555373.89 MWD+IFR-AK-CAZ-SC 10459.27 88.98 359.30 3646.33 .3537.33 4184,31 -3317.29 5949772.02 555372.11 MWD+IFR-AK-CAZ-SC 10556.33 91.28 358.10 3646.11 3537.11 4281.34 -3319.49 5949869.01 555369.15 MWD+IFR-AK-CAZ-SC 10653.60 90.15 357.32 3644.89 3535.89. 4378:52 -3323,38 5949966.15 555364.51 MWD+IFR-AK-CAZ-SC 10749.90 86.62 356.85 3647.61 3538.61 4474.64 -3328.27 5950062.23 555358.87 MWD+IFR-AK-CAZ-SC 10844.14 89.50 356.83 3650.80 3541.80 4568.68 -3333.46 5950156.21 555352.94 MWD+IFR-AK-CAZ-SC 10941.21 89.48 358.45 3651.66 3542.66 4665.66 -3337.46 5950253.14 555348.19 MWD+IFR-AK-CAZ-SC 11039.76 88.74 359.82 3653.19 3544.19 4764.18 -3338.95 5950351.64 555345.93 _MWD+IFR-AK-CAZ-SC 11133.51 88.18 358:89 3655.71 3546.71 4857.89 -3340.00 5950445.33 555344.15 MWD+IFR-AK-CAZ-SC 11226.90 90.29 358.58 3656.96 3547.96 4951.24 -3342.07 5950538.66 555341.36 MWD+IFR-AK-CAZ-SC 11321.18 90.53 358.32 3656.28 3547.28 5045.49 -3344.62 5950632.87 555338.07 MWD+IFR-AK-CAZ-SC 11414.63 90,96 357.38 3655.07 .3546.07- 5138.86 -3348.12 5950726.20 555333.84 MWD+IFR-AK-CAZ-SC 11507.81 89.91 357.63 3654.36 3545.36 5231.95 -3352.18 5950819.25 555329.06 MWD+IFR-AK-CAZ-SC 11601.47 89.73 358.38 3654.65 3545.65 5325.55 -3355.44 5950912.81 555325.07 MWD+IFR-AK-CAZ-SC 11694.51 87.93 0.31 3656.55 3547.55 5418.56 -3356.50 5951005.80 555323.28 MWD+IFR-AK-CAZ-SC i 11787.38 86.69 359.53 3660.91 3551.91 5511.32 -3356.63 5951098.55 555322.43 MWD+IFR-AK-CAZ-SC 11881.26 87.39 0.16 3665.76 3556.76 5605.08 -3356.88 5951192.29 555321.44 MWD+IFR-AK-CAZ-SC ~ ~ 11916.00 87.39 0.16 3667.34 3558.34 5639.78 -3356.79 5951226.99 555321.27 PROJECTED to TD ~ f j ~ '~ `"~' ~:. a~~~ .~. ~ ~o~~i S~c~lberger (;;cCt~rX-i~~i~~"~ ~ NO.3850 ~,) 8 ~?t! Ca69 ~ • ~11C'~141f Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 06/13/06 3J-16 11249908 INJECTION PROFILE 06/03/06 1 1R-OS 11249909 INJECTION PROFILE 06/04/06 1 3H-11 ~ 11213760 PRODUCTION PROFILE W/DEFT 05/31/06 1 1R-07 ~ 11249912 PRODUCTION PROFILE 06/07/06 1 1 F-12 11320981 PRODUCTION PROFILE W/DEFT 06/06/06 1 3G-20 11249911 INJECTION PROFILE 06/06/06 1 2A-16 - 11213754 PRODUCTION PROFILE W/DEFT 05/25/06 1 2A-22 11213756 LDL 05/27/06 1 1Y-04 11320980 LDL 06103/06 1 2Z-02 REDO 11235362 INJECTION PROFILE 05/28/06 1 1H-19 (REDO 11320975 INJECTION PROFILE 05/29/06 1 2A-13 (REDO) 11320976. LDL 05/30/06 1 3J-09 11320977 INJECTION PROFILE 05/31/06 1 1F-17 11249913 PRODUCTION PROFILE W/DEFT 06/08/06 1 1J-170 11320983 USIT 06111/06 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (, 1J-170 A lateral geologic sidetracks Subject: 1J-170 A lateral geologic sidetracks From: "Nugent, David Arnold" <David.A.Nugent(ci;conocophillihs.com Date: Thu, 08 Jim 2006 1 1 :~~):31 -0800 To: t~»1> >T~atmdcr~a;:admir~.stat~.ak.us Tom, I wanted to give you details of our sidetracks on our well. (Sorry about the delay in telling you about the first sidetrack. I was unaware that I had to report it to you until this morning.) Geologic sidetrack PB1 • Well: 1 J-170 • Rig: Doyon 141 • Permit #: 206-062 • Date: June 5, 2006 • Time: 1300 hours • Last casing: 7-5/8" at 7900' • MD of abandoned section: 7990' - 9281' We exited the bottom 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. We are in the process of doing another sidetrack right now. Geologic sidetrack PB2 • Well: 1 J-170 • Rig: Doyon 141 • Permit #: 206-062 • Date: June 8, 2006 • Time: 1000 hours • Last casing: 7-5/8" at 7900' • MD of abandoned section: 11,285' - 11,915' We exited the top of the formation due to geologic uncertainty. We are making a low side sidetrack.. We are planning to isolate the sidetrack by allowing it to collapse. If you have any questions or need additional information, please contact me. Thanks. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska 1 of 2 6/14/2006 2:54 PM ..... .. , ...~ .,.. . ...... .... ...bu~.....vu .. u. r... • Subject; Re: 1 J-170we11 -diverter regulation waiver From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thin, 25 May 2006 09:48:35 -0800 To;"'Nugent, David Arnold" <Day-id.,-~.~ugent~conocophillips.com> ~ G-~~ ~ ~- David, ~Q (~ ~-(~ ~~ With all the improvements and tight spacing on the new pads, avoiding conflicts is difficult. I understand the intent of angling 141's diverter line away from 15's rockwasher. From your description and the drawing, the "bend" does not appear to be abrupt. Dramatic changes in direction are of concern if the diverter were to be needed. The angled layout you propose is acceptable. Again, a copy of this message should be available on both rigs. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 5/25/2006 8:46 AM: Tom, We had to make a change on our diverter drawing we sent you the other day. We fiound out it was longer than we thought, and we decided to angle it away from the rock washer for Doyon Rig 15. I attached the new drawing showing the diverter line for Doyon 141 for the 1J-170 weft. We have about a 15 degree bend in the line. We are requesting a waiver as before. We should be releasing Doyon 141 around 1800 hours today to move to the 1J-170 welt. f will call you shortly to discuss. Thanks. David A. iVugent -----Original Message----- From: Thomas Maunder [mailtoaom maunder@admin.state.ak.us] Sent: Wednesday, May 24, 2006 8:45 AM To: Nugent, David Arnold Subject: Re: 1J-170we11 -diverter regulation waiver David, It is acceptable to site the rigs as you have diagrammed. The "encroachment" is small and you have a contingency plan in place for communication and coordination between the rigs. Also, as you note gas has not been seen in the surface holes of the wells recently drilled on 1J. A copy of this message should be sent to both rigs. Call or message with any questions. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 5/22/2006 4:46 PM: 1 of 2 5/26/2006 7:09 AM Re: 1J-170we11-diverter regulation waiver Subject: Re: 1J-170we11 -diverter regulation waiver From: Thomas Maunder <_toi7~ maunder~admin.state.ak.us= Dater Wed,'24 May 200(; i)8:4~:20 -0~00~ To: "Nu~enL David Artlold" <David.~.Nu~entCci~~conocopliilliPs.conl> David, It is acceptable to site the rigs as you have diagrammed. The "encroachment" is small and you have a contingency plan in place for communication and coordination between the rigs. Also, as you note gas has not been seen in the surface holes of the wells recently drilled on 1 J. A copy of this message should be sent to both rigs. Call or message with any questions. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 5/22/2006 4:46 PM: Tom, We will be moving the Doyon 141 rig to the 1J-170 location in the next few days (Permit number ~,~ ' 206-062). I am attaching a drawing of how Doyon 141 and Doyon 15 rigs will be situated on the 1J pad. Doyon 15 is currently drilling the 1 J-127 well. The red circle on the drawing between Rig 141 and Rig 15 is a 75' radius circle centered at the end of the diverter vent line from Rig 141 when the rig is on location ready to drill the 1J-170 well. Regulation 20 ACC 25.035 (c) (1) (C) (i) states that the diverter vent line must extend to a point at least 75 feet away from a potential source of ignition. As seen from the drawing, the vent line from Doyon 141 is at least 75 feet away from Doyon 15 everywhere but on one corner of the rig. However, it does barely touch the corner of Doyon 15, and we request a waiver of this section of the regulation so Doyon 141 can work from this location. We have drilled 8 wells from the J pad and have seen no evidence of gas in the surface hole portion of these wells and are not expecting any gas in the surface hole of the 1J-170 well. We have phone communication and radio communication between the two rigs, and Doyon 15 would be notified immediately if the 1J-170 well was put on diverter. If you have any questions, please contact me. I will be at the Doyon 141 rig tomorrow, and can be contacted via a-mail or cell at 244-5946. I will be back in the office on Wednesday. «1J Site Plan June 1.pdf» Thank you. David A. Nugent Staff Drilling Engineer ', ConocoPhillips Alaska 907-265-6862 (office) 918-662-6886 (fax) 1 of 1 5/24/2006 8:53 AM • o~ :s Doyon Drilling Rig #147 Sul•. ANSI B Six•: '." • tO IMI __ I SW.. •X310 Siza: t"•rO Mr •-55, a~~ 111 Legend O GcYU LNbr iMkaYz ftlp 15 °rpnp Ortln ~acf JVortFi ~ vrec xa~.~.~.+a „~. rwrza I 0 75 150 215 900 Scale: ANSI 8: 1/2 inch = 75 R ANSI D' 1 inch = 75 R CortO°oraa.n s(br x•N n.mM n qM brM c0/I.YCro..MfvpnP00wM w.AalNMnprwn. CompWM rnVY Mr NW Yu°M n yNUw. \\ ~ .a" ,_ __. .. '., .' 1 ~' ~s~ -- W .. _. ~ ..~ ~: ~~ ~~~~; ~i.~.,.-. ~~ i 1 _ ~~ ® ~~ L ~ ® ~_-~ ~~ i' 1 r.r. I a I d ~ ;.oo ~ o ~a . i ~ i + d a` i A i ~i ~ 1 ~ Jli a iue..: a .~..... ...-.. d?g~ ... ' o... i ` ~._.__. _...T • j T d ~..-. j ~.,...n. 0 '-- w.tr,e. C~"' T ~ ~- s ~.m _..... ~ ~Q' wnNlutM a ~ s r.ao 0 ~ uuln ~~,~ ,. Q w ",' O :..nn.,N ;?A $ Nip 1~1 y" ~g ~....~ ,.~ 8 - ' -~.. ---- a ~, ._ ~I,t.N.. ~~ a VSM. rypiul, b , u~lawn ~ I hN Mnlntl M.M. ' ~ aµ- rn, LJ topbbt' <' - IatM• (/: I I ~ ~_ ~ P.p-.. ~~ I I ~. , I I '. % ai .... .-.. E~ ro. d~ ~i ~~ r ~~ i a a s ~ !g Its s s 1J Pad West Sak Drilling June 1, 2006: Rig 141 on 1J-170, Rig 15 P,.P.nenysr.~.M°K..w. +i srm oP. s~ro w.. c..n.c V.a ConocoPhillips 5°••"°" Alaska on 1J-127 ~~°°~ DAlll Order of 7117/06 ........... ..1 15' G ......._ ......... Doyon DAlling Rig #1b SuN. ANSI B Sizr Y.' •.p M1 5c.1.. •Nil o slz.~. r • ~o Iwl --=aos~ o•---. r~ ~~ • FRANK H. MURKOWSKI, GOVERNOR Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-170 ConocoPhillips Alaska, Inc. Permit No: 206-062 Surface Location: 1802' FSL, 2490' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 2724' FSL, 570' FEL, SEC. 27, T11N, RlOE, 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 l'6day of May, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 5, 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-170, 1J-170 Li, iJ-170 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a trilateral horizontal well in the West Sak "A2", "B"and "D" sands. The main bore of the well will be designated 1J- 170, and the lateral bores of the well will be designated iJ-170L1 and iJ-170L2. 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 1J-170 is June 1, 2006. If you have any questions or require any further information, please contact David Nugent 265-6862. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader RT/DN/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 V.1G/~- S I t~ f 2.004 ~, ~--- ~ ~~,~~ g~ ~v ~i1 1a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service 0 • ~ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for. 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-170 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12508' TVD: 3643' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1802' FSL, 2490' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25660 / 2S"(.4 t y z:~west Sak Oil Pool Top of Productive Horizon: 3190' FSL, 635' FEL, Sec. 34, T11 N, R10E, UM 8. Land Use Permit: ALK 470 13. Approximate Spud Date: 6/1!2006 Total Depth: 2724' FSL, 570' FEL, Sec. 27, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: <3 miles to KRU . 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558722 - y- 5945614 ' Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Near ~ t~,_ /O ,,. S~ Well within Pool: 1J-1 • ~~~ 16. Deviated wells: Kickoff depth: 300 ft. • Maximum Hole Angle: 91 ° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035 Downhole: 1639 psig ~ Surface: 239 sig ' 18. Casing Program if ti S Setting Depth antity of Cement Size ica ons pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 3018' 28' 28' 3018' . 2145' 530 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7.625" 29.7# L-80 BTCM 7681' 28' 28' 7681' • 3619' 430 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 5824' 6684' 3447' 12508' • 3643' - slotted liner 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 ^/ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 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 David Nugent @ 265-6862 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` - Phone "LUG ~~ 3 O Date j / S/o r h r n All Dra Commission Use Only Permit to D'rill^ Number: 11~~p ^ 0 ~Z API Number: 50- ~ .~ - Z3 3 /a ~©~ Permit Approval Date: ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [r]'• Other: 1L p ~ ,H2S measures: Yes ^ No irectional sv req'd1: Yes [V]/ No ^ Te ~ l ~ ~ t r •'~ 3 0 0 0 ~/I sc, t~ a -~w jWt. u, tw... /1Gl LT t 2 9 u~. ~ '~ Go G rt~ tc,i wt / / - D ~ APPROVED BY THE COMMISSION DATE: ~ b Form 10-401 Revised 12/2005 m . ~.~ (~ "~ '1 rZ.~ COMMISSION ~ ~~~ Submit in Duplicate ~- S •/Z •06 ~ation for Permit to Drill, Well 1J-170 Revision No.0 Saved: 3-May-06 Permit It -West Sak Well #1J-170 •~°~ f.A ~~l Application for Permit to Drill Document f~1~Well MdxirriiaE 1M~11 Vplt~~ Table of Contents 1. Well Name ................................................................................................................. 2 Re uirements of 20 AAC 25.005 .................................... 2 p (1) ................................................................... 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 ........................................... 4 Requirements of 20 AAC 25.005 (c) (5) .................................................................................................. 4 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) ...............................................................................:.. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 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 ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 not done 1J-170 PERMIT IT Page 1 of 8 Printed: 3-May-06 ORIGINAL ~ation for Permit to Drill, Well 1 J-170 Revision No.0 Saved: 3-May-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 ............................................~-~-~--......................---.....................---............ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary .............................................................:......... 8 Attachment 4 Well Schematic ........-~-~-~ ................................................................................................. 8 Attachment 5 1/4 Mile Radius Effect for Injector ......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the aperator and a unique API number assigned by the commission under 2IJ AAC 25. Q40(b). Far a we/J with mu/tip/e wel/branches, each branch must sr`milar/y be identif<ed by a unique name andAPl number by adding a suffix to the name designated far the well by the operator and to the number assigned to the wel/ by the COmmf55lOn. The well for which this Application is submitted will be designated as iJ-170. 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 file with the commission and identified in the application; (2) a plat identifying the property and the proper(y`s owners and showing (A)the coordinates of the proposed /ocation of the wel/ at the surface, at the tap of each objective formation, and at total depth, referenced to governmenta/section lines. (,8) the coordinates of the proposed location of the we// at the surface, referenced to the state p/one coordinate system for this state as maintained by the Nationa! Geodetic Survey in the Nationa/ Oceanic and Atmospheric Administration; (C) the proposed depth of the we/l at the top of each objective formation and at total depth; Location at Surface 1 802' FSL, 2,489` FEL, Section 35, T11N, R10E - ASPZone 4 NAD 27 Coordinates RKB E/evatiOn 109.0' AMSL Northings: 5,945,614 "Eastings: 558,722 Pad E/evation 81.0' AMSL Location at Top of Productive Interval West Sak °A2" Sand 3190' FSL, 635' FEL, Section 34, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.• 7 681 Northings: 5,946,975 .Eastings: 555,285 Tota/ l/ertica/De th, RKB.• 3 619 Tota/ t/ertica/ De th SS.• 3,510 Location at Total De th 2724' FSL, 570' FEL Section 27, Ti1N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB; 12, 508 Northings; 5,951,789 Eastings.• 555,307 Tota/ l/ertica/De th, RKB.• 3,643 Total vertical De th, SS.• 3 534 not done 1J-170 PERMIT IT Page 2 of 8 Printed: 3-May-O6 ORIGINAL ~ation for Permit to Drill, Well 1J-170 Revision No.0 Saved: 3-May-O6 and (Q) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) If a we// is to be intentionally deviated, the app/icatian far a Permit to Drill (Farm 10-401) must (1) inclade a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including al/ adjacent we//bores within 200 feet of any pardon of the proposed we/% Please see Attachment 1: Directional Plan and (2) far a// we!/s withr`n 200 feet of the proposed wel/bore (A) list the names of the operators of those wel/s, to the extent that thase names are known ar discaverable in public records, and Shaw that each named operator has been furnished a cagy of the app/icatian by certiFed mail; or (B) state that the app/icant is the anly affected awner: 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 fo/%wing items, except for an item already on fi/e with the commission and identi/ed in the application: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-170. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, - = blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 ~ psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An apply""cation for a Permit to Dri/l must 6e accompanied by each of the fol/owing items, except for an item a/ready on file with the commission and identified in the app/ication: (4) information on drilling hazards, including (A) the maximum downhole 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 1,239 psi, calculated thusly: MPSP = (3,643 ft TVD)(0.45 - 0.11 psi/ft) = 1,239 psi (B) data on potential gas zanes; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnormal/y geo pressured strata, lost circa/anon zones, and zones that have a propensity for differentia/sticking; Please see Attachment 2: 1J-170 Drilling Hazards Summary. ORIGINAL not done 1J-170 PERMIT IT Page 3 of 8 Printed: 3-May-O6 • ~ation for Permit to Drill, Well 1 J-170 Revision No.O Saved: 4-May-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application far a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready on fr/e with the commission and identified in the application; (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 2S. D3D(~; iJ-170 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 applcation far a Permit to Dri// must be accompanied by each of the following items, except for an item already on fr/e wfth the commission and identified m the application; (6) a comp/ete proposed casing and cementing program as required by 20 AAC' 25.03D, and a description of any slotted liner, pre- pen`arated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole ~ / Top Btm 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 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 _ _ _ 13-1/2 45.5 L-80 special 3,018 28 / 28 3,018 /2,145 530 sx ASLite Lead, drift 180 sx DeepCRETE Tail Cement Top planned @ 7-5/$ 9-7/8 29.7 L-80 BTCM 7,681 28 / 28 7,681 / 3,619 4.200` MD / 2,637 TVD. Cemented w/ 430 sx Dee CRETE 4-1/2 6-314" A Sand 11.6 L-80 BTC 5,$24 6,684 / 3,447 12,508 / 3,643 Slotted- no cement slotted Lateral (1J-170) 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 6,065 6,584 / 3,434 12,649 / 3,525 Slotted- no cement slotted Lateral (1J-170 Ll) 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 6,598 6,138 / 3,347 12,736 / 3,470 Slotted- no cement slotted LateraV (i]-170 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/icatr"on for a Pemtit to Drill must be accompanied 6y each of the following items, except far an item already on fife with the commission and identified in the application; (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 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 iJ-166. Please see diagrams of the Doyon 141 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 Dri/l must be accompanieed by each of the following items, except for an item already on file with the commission and identified in the application; (8) a dri/ling tluidprogram, including a diagram and description of the dri0ling fluid system, as required by 2D AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: not done 1J-170 PERMIT IT Page 4 of 8 Printed: 4-May-06 ORIGINAL Surface Hole Mud Program (extended bentonite) ~ation for Permit to Drill, well 1J-170 Revision No.O Saved: 3-May-06 S ud to Base of Permafrost Base of Permafrost to 10-3/4"Casio Point Initial Value Final a Initial Value Final Value Density (ppg) 8.9 9.2 9.5 9.6 Funnel Viscosity 150 0 200 300 seconds Yield Point 50 70 30 50 cP Plastic Viscostiy 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 ,4P/ Filtrate. NC 8 0 0 5 7 0 cc / 30 min . . . *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 seconds 45 - 60 Plastic Viscostiy 12 - 18 Ib/100 s Yield Point 26 - 35 cP API Filtrate cc / 30 min 4 - 6 Chlorides (mg/I) <500 pH 9.0 - 9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals _ Value Densit pp 8.8 Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 18 - 28 cP ___ HTHP Fluid loss (ml/30 min @ <4.0 200 si 8 150° Oil /Water Ratio 70 / 30 Electrical >600 Stabilit 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 141. 9. Abnormally Pressured Formation Information. Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to IJrill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the app/ication: (9) for an exp/oratory or stratigraphic test we/l, a tabu/ation setting aut the depths of predicted abnormafly qeo pressured strata as required by 20 AAC25. (733(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 Dri/I must be accompanied by each of the following items, except far an item a/ready on frle with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel% a seismic refraction or reflection analysis as required by 20 AAC 25.Ob1(a,; Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL not done 1J-170 PERMIT IT Page 5 of 8 Printed: 3-May-06 ~ation for Permit to Drill, Well 1J-170 Revision No.O Saved: 3-May-06 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application 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: (11) far a well dri/!ed from an offshore platform, mobile bottom-founded structure, jack-up rig, ar t7oating drillr`ng vess% an analysis ofseabed conditions as required by ~0 AAC25. F~&1(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application; (12) evidence showing that the rec7uirements of ZD AAC 25. t125 {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 Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication; 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 +/- 108' RKB. Install landing ring on conductor. 2. Move in / rigup Doyon Rig. 141. 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 +/- 3,018' MD / 2,145' 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 7,681' MD / 3,619' TVD, the prognosis top of the A2 sand. ~ 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 4,200' MD / 2,637' TVD if Ugnu C formation is oil bearing. Top of cement to be 500. feet (MD) above shallowest oil bearing 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 12.5 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 12,508' MD / 3,643' TVD as per directional plan. not done 1J-170 PERMIT IT Page 6 of 8 Printed.• 3-May-06 ORIGINAL ~ation for Perrnit to Drifl, Well 1J-170 Revision No.0 Saved: 3-May-06 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. PU and run 4-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 6,684' MD / 3,447' TVD. POOH. Note: Remaining operations are covered under the iJ-170L1 Application for Permit to Drill, and are % provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,584' MD / 3,434' TVD, the top of the B sand. 19. Mill 6-3/4" window. POOH. 20. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at +/- 12,649' MD / 3,525' TVD, as per directional plan. 22. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool..... POOH. 27. 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 iJ-170L2 Application for Permit to Drill, and are ~ - provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,138' MD / 3,347' TVD, the top of the D sand. 29. Mill 6-3/4"window. POOH. 30. Pick up 6-3/4"drilling assembly with LWD and -MWD and PWD. RIH. 31. Drill to TD of D sand lateral at +/- 12,736' MD / 3,470' TVD, as per directional plan. 32. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH orr elevators. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4-1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool. POOH. 37. 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. 38. POOH, laying down drill pipe as required. 39. PU injection completion and RIH to depth. Land tubing. Set BPV. 40. Nipple down BOPE, nipple up tree and test. Pull BPV. 41. Freeze protect well with diesel not done 1J-170 PERMIT IT Page 7 of 8 Printed: 3-May-O6 ,~ation for Permit to Drill, Well 1J-170 Revision No.O Saved: 4-May-06 42. Set BPV and. move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fr/e with the commission and identified in the application.• (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. t?80 for an annular disposal operation m the we/1.; Waste fluids generated during the drilling process .will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 1J 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 Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 BOP Configuration Attachment 5 Well Schematic OR161NAL not done 1J-170 PERMIT IT Page 8 of 8 Printed: 4-May-O6 ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-170 -Slot 1J-170 1 J-170 Plan: 1J-170 (wp05) Proposal Report 10 April, 2006 ~iperii~ I~rillin~ S~eir~ric+es oR!ciNa~ Project: Kuparuk River Unit ~~ ''-•~-#..~~`~L~ ~" ~~ CASwG DeTAILs Site: Kuparuk 1J Pad i~ ~rr7+Dr111ing Servk:es C©i"iQ[C~11~~1~15 No TVD MD Name Size Well: Plan 1J-170 ,' ~'~~~ 1 8o.oa ao.oo zo° zo Welibore: 1J-170 KOP @ 300ft MD, 300ft TVD -Build @ 2.5°/100 2 2145.00 3018.00 10 3/4" 10-3/4 Plan: 1J-170 (wp05) ~~ ~ a 3643.00 12508.49 41/2" 4-1/2 ~ ~ Continue Build @ 4°/100ft , 700ft MD, 700ft TV i i i i SHL@1802ftFSL82489ftFEL-Sec 35-T11N-R7,6 ' , ~i Sail @ 47° Inc : 1630ft MD, 1500ft TV FORMATION TOP DETAILS -400 ~ ~ ~ ,' ,' No. TVDPath TVDSS MDPath Farmation i i Continue Build @ 4.5°/100ft , 1730ft MD, 1568ft TV 1 1521.00 1412 1880.56 Base Perm i ~ 2 1634.00 1525 1831.32 T3 0 20' 3 1928.00 1817 2470,10 K15 . ~ d 2145.00 2036 3018.00 T3+550 ~ 5 2838.00 2729 4700.85 Ugnu C C r ~ 5 3043.00 2934 5193.38 Ugnu B i Sail @ 66.4°Inc & 233°Azi : 2158ft MD, 1801ft TV ° 7 3130.00 3021 5414.46 Ugnu A 0 $ 3216.00 3107 5655.66 K13 9 3347.00 3238 6138.32 Wsak D ~ 10 3391.00 3282 6347.21 Wsak C ' ~ 11 3433.96 3325 6583.87 Wsak B 10° 12 3469A0 3360 6785.68 Wsak A4 13 3526.00 3417 7113.93 Wsak A3 10 3l4^ Csg @ 3018ft MD, 2145ft Tv 14 3618.88 3510 7676.83 Wsak A2 ?0° 30~ ,~ 40,. -------------- ___-- -~~~~-------__________- ----- r ~ ----------___-____-----____BasePerm______-- --- - --- - -- ------ ------- -, - T3------ - ' Continue Tum @ 4.5°/100ft , 3158ft MD, 2200ft TV - - - - - - - - - - - _~ ~ - - - - - _ - _ ~ - - Min !nc During Turn - 64.6°, 3700ft MD, 2429ft TV - - __ ---- --------------------------- K95 ----- ~ ----------°=------------------------------------- '{ _ - ------------------------------------ T3+550 _ - - - Sail @ 66.4°Inc 8 280°Azi : 4116ft MD, 2603ft TV - - ° 1J-170 LZ (wp05 _ - Continue BuildlTum @ 5 /100ft , 4546ft MD, 2775ft TV - 6 _ _ _ - - - - - 6 _ _ - - - Sail @ 80°Inc & 2°Azi : 6584ft MD, 3434ft TVD --- 1J-170 L1 (wp05 i ~ ~ i --- ----------------------------r?--------------------------- ---- -------------------------- UgnuC---~~----~-- i 1J-170 T1 Dtap (wp05 ,' Continue Build @ 4°/100ft , 7556ft MD, 3603ft TV~ 1J-170 T5 {wp05 ~ i ' -- ~------ U nuB--------`--- ~-- - - - - - - c ~ iJ=170 T3 w 05 _ _ -------- --q___---~------__..~-------------,-- 1J-170 T2{wp05__ { P ~ ~ ~ _---------- ~.-_. - .-1... _....--_ ~ _. -_-tDgP51AA-_- _\_-~-- - - - - - - - -.- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -i- - - - - - - - - - - - - - ' - - - - - - - - - - - - - - - - - - - - - - - K13 - - - - - - - - -'~- - -~ - - i g i - - - - - - - - - - - - - - - -0p' - - - - - - - - - - -- - - - - - - _~ - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - `- -I - - _ _ - - - - - - ~ - -. - - - - -~- - - .- _.- - - - - - - - _ - - - - -_ - -_ T - - - - - - - - - - - - - - - - .~ - - - - - - - - - - - - - - - - - - - - - - _ = WsakD -~-- -- -- ---- - ~- -- --- ...- r - \~- - -- ~ --- - o c / ~~ `~ wsakc ~ ~ ~ _ ~~~ ~ 1J-170 (wp05) , \ ~~ ~ Wsak B i ~~ \~ 1J-170 T4 {wp05 ~ i ~ ~- 1J-170 TO (wp05 ~ ~' i ~ ~\ ~ Wsak A4 i ~~ 7 5/8" Csg @ 7681ft MD, 3619ft TV ~ ~ 1J-170 T7 (wp05 i ' \ Wsak A2 1R°sak A3 ~ ~ Turn @ 3°/100ft, 6511ft MD, 3421ft TV ~ i - 1J-170 TS Tae {wp05 ~ i Build @ 0.8°/100ft to 80° lint - 6138ft MD, 3347ft TV Build @ 4°/100ft, 7700ft MD, 3620ft i TVD -Continue Geo-Steer in Upper Lobe A2 Sad Sail @ 77°Inc & 359.°Azi : 6053ft MD, 3328ft TV TD @ 12508ft MD, 3643ft TVD - 41l -1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 `~~rfit:,^I Sc::;iion ~9 f?.Ofi° (~~ ~? ~ff,`irrj 81 31 -31 1J-170 L2(wp05 1J-170 L7 (wp05 1J-170 T8 7oe {wp05 - - 1J-176 T7 {wp05 - 1J-170 T6 (wp05 / - 1J-170 T5 {wp05 _ L V O 0 c w 0 u7 N ... 1J-170 T4 {wp05 L O 1J-170 T3 (.vp05 Z L 1J-170 T2 {wp05 0 Sail @ 80°Inc & 2°Azi ; 6584ft MD, 3434ft TVD Tum@3°/t00ft,6511ftMD,3421ft TV Project: Kuparuk River Unit Sit K r k 1 J P d ~ CASING DETAILS e: upa u a Well: Plan 1J-170 No TVD MD Name Size Wellbore: 1J-170 1 80.00 80.00 20" 20 Plan: 1J-170 (wp05) 2 2145.00 3018.00 10 3/4" 10-3/4 3 3619 05 7680 87 7 5/8" 5/8 7 . . - 4 3643.00 12508.49 4 1 /2" 4-1 /2 T ty~ Magnetic North: Magnetic Strength:.5756 Dip Angle: f TD 12508ft MD, 3643ft TV - Date: 6/1 e° Model: BGGt, a 1/3^_ - FiAt _... Sperry DHillerg Sarvtcas CQno+coPh~llips 1°°~ 1 l I` D!0 ®D Roiyon Describes a corridor 1Q0° wide I with a 9~'+!- ailowancs frorn the praposed weiibare. 7 5/8" Csg @ 7681ft MD, 3619ft TV Build @ 4°/100ft, 7700ft MD, 3620ft TVD -Continue Geo-Steer in Upper Lobe A2 Sa d - - - - - - - - - - Continue Build @ 4°/100ft , 7556ft MD, 3603ft TV Build @ 0.8°/100ft to 80° lint - 6138ft MD, 3347ft TV 1J-170 T1 Dtop (wp05 350° ~tiy 0 00 0 0 ~ Sail @ 77°Inc & 359.°Azi ; 6053ft MD, 3328ft TV ~ ~' N ~ No N SHL @ 1802ft FSL & 2489ft FEL -Sec 35 - T11 N - R10E 20' / L, - - - - - - KOP @ 300ft MD, 300ft TVD -Build @ 2.5°1160 Boo Continue Build @ 4°/100ft , 700ft MD, 700ft TV ~ BB ~ , B ~' ~ \~ Sail @ 47°Inc : 1630ft MD, 1500ft TV ~ I i ` ~ ~ I ~ / I ~ \\~ i \ ~ Continue Build @ 4.5°/100ft , 1730ft MD, 1568ft TV~ Continue BuildlTum @ 5°/t00ft , 4546ft MD, 2775ft TV ~ ~ , ` ~ ~ ~ i ~ ~~ i ~ i ` ~ i ~ i i ~ Sail @ 66.4°Inc 8:280°Azi : 4116ft MD, 2603ft TV ~ ~ ` i ~ ~ ~ ~ i~ ~ i ~ Continue Tum @ 4.5°/100ft , 3158ft MD, 2200ft TV `\ Sail @ 66.4°Inc & 233°Azi : 2158ft MD, 7801ft TV I Min Inc During Turn - 64.6°, 3700ft MD, 2429ft TV 10 3/4" Csg @ 3018ft MD, 2145ft TV -6250 -5625 -5000 -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 ... .~ J(Vest1-)GEacf(~ (1250 ftrn) ~ Halliburton Energy Services ° - C ' PI w _ :~~r~ s-a~~~~ ~~ ~ +C~1 10CC1 ~Il S 1 Planning Report -Geographic -- - Alaska Sperry Drilling S~rvic~s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+g1)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: iJ-170 Design: 1J-170 (wp05) 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-170 - Slot iJ-170 Well Position +N/-S 0.00 ft Northing: 5,945,614.10 ft Latitude: 70° 15' 43.258" N +E/-W 0.00 ft Easting: 558,721.61 ft Longitude: 149° 31' 31.065" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-170 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 6/1/2006 24.0717 80.7728 57,565 --- -- - Design 1J-170 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 0.00 4/10/2006 10:38:03AM Page 2 of 10 V ~~ ~~~~~ COMPASS 2003.11 Build 50 Halliburton Energy Services Ct~n©CC?PhII~pS Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-170 Wellbore: 1J-170 Design: 1J-170 (wp05) " ' ~~ -r':~="-° Sparry Frilling Services Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/_g +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.0000 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.0000 700.00 10.00 233.00 697.97 -20.95 -27.81 2.50 2.50 0.00 233.0000 1,629.66 47.19 233.00 1,500.00 -284.04 -376.94 4.00 4.00 0.00 0.0000 1,729.66 47.19 233.00 1,567.96 -328.19 -435.52 0.00 0.00 0.00 0.0000 2,157.52 66.44 233.00 1,801.06 -542.67 -720.14 4.50 4.50 0.00 0.0000 3,157.52 66.44 233.00 2,200.77 -1,094.32 -1,452.21 0.00 0.00 0.00 0.0000 4,116.00 66.44 280.28 2,603.07 -1,289.60 -2,274.48 4.50 0.00 4.93 99.9260 4,545.89 66.44 280.28 2,774.91 -1,219.27 -2,662.20 0.00 0.00 0.00 0.0000 6,053.32 77.00 359.79 3,327.88 -211.93 -3,463.75 5.00 0.70 5.27 98.0369 6,138.32 77.00 359.79 3,347.00 -129.10 -3,464.05 0.00 0.00 0.00 0.0000 6,511.32 80.00 359.79 3,421.36 236.36 -3,465.39 0.80 0.80 0.00 0.0000 6,583.87 80.00 2.00 3,433.95 307.79 -3,464.28 3.00 0.00 3.05 90.1919 7,555.87 80.00 2.00 3,602.74 1,264.44 -3,430.87 0.00 0.00 0.00 0.0000 7,680.87 85.00 2.00 3,619.05 1,388.26 -3,426.55 4.00 4.00 0.00 0.0000 7,700.87. 85.00 2.00 3,620.79 1,408.17 -3,425.85 0.00 0.00 0.00. 0.0000 7,981.69 90.30 11.91 3,632.33 1,686.24 -3,391.87 4.00 1.89 3.53 62.1189 8,242.46 90.30 11.91 3,630.96 1,941.39 -3,338.03 0.00 0.00 0.00 0.0000 8,263.25 89.47 11.91 3,631.00 1,961.73 -3,333.74 4.00 -4.00 -0.02 -179.6607 8,402.98 89.40 7.72 3,632.38 2,099.37 -3,309.93 3.00 -0.05 -3.00 -91.0063 8,509.45 89.40 7.72 3,633.50 2,204.88 -3,295.63 0.00 0.00 0.00 0.0000 8,783.80 91.48 358.06 3,631.40 2,478.53 -3,281.81 3.60 0.76 -3.52 -77.8498 8,877.20 91.48 358.06 3,629.00 2,571.84 -3,284.97 0.00 0.00 0.00 0.0000 8,954.40 90.09 358.74 3,627.95 2,649.01 -3,287.13 2.00 -1.80 0.87 154.0955 11,576.68 90.09 358.74 3,624.00 5,270.65 -3,344.93 0.00 0.00 0.00. 0.0000 11,611.11 89.40 358.73 3,624.16 5,305.07 -3,345.70 2.00 -2.00. -0.03 -179.2722 11,976.92 89.40 358.73 3,628.00 5,670.77 -3,353.82 0.00 0.00 0.00 0.0000 12,012.83 88.68 358.73 3,628.60 5,706.67 -3,354.61 2.00 -2.00 0.00 179.9686 12,377.24 88.68 358.73 3,637.00 6,070.89 -3,362.70 0.00 0.00 0.00 0.0000 12,481.16 86.53 357.95 3,641.34 6,174.67 -3,365.70 2.20 -2.07 -0.75 -160.2377 12,508.50 86.53 357.95 3,643.00 6,201.94 -3,366.67 0.00 0.00 0.00 0.0000 4/10/2006 10:38:03AM Page 3 of 10 I~~~... COMPASS 2003.11 Build 50 Halliburton Ener Services C~J1"tC}CC~~~I~~1 S 9Y ._ ~. a..: ; ~ .y Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-170 Wellbore: 1J-170 Design: 1J-170 (wp05) Sperry OriillFng Services Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-170 (wp05) MD Inclination Azimuth TVD SSTVD +N/-S (ft) (°) (°) (ft) (ft) (ft) 28.00 0.00 0.00 28.00 -81.00 0.00 SHL @ 180 2ft FSL & 2489ft FEL -Sec 35 - T11 N - R10E 80.00 0.00 0.00 80.00 -29.00 0.00 20" 100.00 0.00 0.00 100.00 -9.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 KOP @ 300ft MD, 300ft TVD -Build @ 2.5°/100ft 400.00 2.50 233.00 399.97 290.97 -1.31 500.00 5.00 233.00 499.75 390.75 -5.25 600.00 7.50 233.00 599.14 490.14 -11.80 700.00 10.00 233.00 697.97 588.97 -20.95 Continue Build @ 4°/1 00ft , 700ft MD, 700ft TVD 800.00 14.00 233.00 795.77 686.77 -33.46 900.00 18.00 233.00 891.87 782.87 -50.05 1,000.00 22.00 233.00 985.82 876.82 -70.63 1,100.00 26.00 233.00 1,077.16 968.16 -95.10 1,200.00 30.00 233.00 1,.165.44 1,056.44 -123.35 1,300.00 34.00 233.00 1,250.22 1,141.22 -155.23 1,400.00 38.00 233.00 1,331.11 1,222.11 -190.60 1,500.00 42.00 233.00 1,407.70 1,298.70 -229.28 1,600.00 46.00 233.00 1,479.62 1,370.62 -271.07 1,629.66 47.19 233.00 1,500.00 1,391.00 -284.04 Sail @ 47° Inc : 1630ft MD, 1500ft TVD 1,660.56 47.19 233.00 1,521.00 1,412.00 -297.68 Base Perm 1,700.00 47.19 233.00 1,547.80 1,438.80 -315.09 1,729.66 47.19 233.00 1,567.96 1,458.96 -328.19 Continue Build @ 4.5°i100ft , 1730ft MD, 1568ft TVD 1,800.00 50.35 233.00 1,614.32 1,505.32 -360.02 1,831.32 51.76 233.00 1,634.00 1,525.00 -374.68 T3 1,900.00 54.85 233.00 1,675.04 1,566.04 -407.82 2,000.00 59.35 233.00 1,729.34 1,620.34 -458.34 2,100.00 63.85 233.00 1,776.88 1,667.88 -511.26 2,157.52 66.44 233.00 1,801.06 1,692.06 -542.67 Sail @ 66.4°Inc & 233°Azi : 2158ft MD, 1801ft TVD 2,200.00 66.44 233.00 1,818.04 1,709.04 -566.10 2,300.00 66.44 233.00 1,858.01 1,749.01 -621.27 2,400.00 66.44 233.00 1,897.98 1,788.98 -676.43 2,470.10 66.44 233.00 1,926.00 1,817.00 -715.10 K15 Map Map +E/-W Northing Easting DLSEV Vert Section (ft) (ft) (ft) (°1100ft) (ft) 0.00 5,945,614.10 558,721.61 0.00 0.00 0.00 5,945,614.10 558,721.61 0.00 0.00 0.00 5,945,614.10 558,721.61 0.00 0.00 0.00 5,945,614.10 558,721.61 .0.00 0.00 0.00 5,945,614.10 558,721.61 0.00 0.00 -1.74 5,945,612.77 558,719.88 2.50 -1.31 -6.96 5,945,608.80 558,714.69 2.50 -5.25 -15.66 5,945,602.18 558,706.05 2.50 -11.80 -27.81 5,945,592.93 558,693.97 2.50 -20.95 -44.41 5,945,580.29 558,677.47 4.00 -33.46 -66.42 5,945,563.54 558,655.59 4.00 -50.05 -93.73 5,945,542.75 558,628.45 4.00 -70.63 -126.20 5,945,518.03 558,596.16 4.00 -95.10 -163.69 5,945,489.49 558,558.90 4.00 -123.35 -206.00 5,945,457.28 558,516.84 4.00 -155.23 -252.94 5,945,421.55 558,470.19 4.00 -190.60 -304.26 5,945,382.48 558,419.18 4.00 -229.28 -359.73 5,945,340.26 558,364.04 4.00 -271.07 -376.94 5,945,327.16 558,346.94 4.00 -284.04 -395.04 5,945,313.37 558,328.94 -418.14 5,945,295.79 558,305.98 -435.52 5,945,282.56 558,288.70 -477.76 5,945,250.40 558,246.71 -497.22 5,945,235.59 558,227.38 -541.19 5,945,202.11 -608.23 5,945,151.08 -678.47 5,945,097.61 -720.14 5,945,065.89 558,183.67 558,117.03 558,047.22 558,005.79 -751.24 5,945,042.21 -824.45 5,944,986.48 -897.66 5,944,930.75 -948.98 5,944,891.69 2,500.00 66.44 233.00 1,937.95 1,828.95 -731.60 -970.86 5,944,875.02 2,600.00 66.44 233.00 1,977.92 1,868.92 -786.76 -1,044.07 5,944,819.30 2,700.00 66.44 233.00 2,017.89 1,908.89 -841.93 -1,117.28 5,944,763.57 557,974.88 557,902.11 557,829.34 557,778.33 557,756.57 557,683.81 557,611.04 0.00 -297.68 0.00 -315.09 0.00 -328.19 4.50 -360.02 4.50 -374.68 4.50 -407.82 4.50 -458.34 4.50 -511.26 4.50 -542.67 0.00 -566.10 0.00 -621.27 0.00 -676.43 0.00 -715.10 0.00 -731.60 0.00 -786.76 0.00 -841.93 4/10/2006 10:38:03AM Page 4 of 10 COMPASS 2003.11 Build 50 FINAL Halliburton Energy Services > .~. ~t~1'1OCC?~~"1I~IpS Pl i R rt G hi ann ng - epo eograp c AI~Ska Sperry tlrilling Sarvice5 Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1J-170 Design: 1J-170 (wp05) Planned Survey 1J-170 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +NI-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 2,800.00 66.44 233.00 2,057.86 1,948.86 -897.09 -1,190.48 5,944,707.84 557,538.27 0.00 -897.09 2,900.00 66.44 233.00 2,097.83 1,988.83 -952.26 -1,263.69 5,944,652.11 557,465.51 0.00 -952.26 3,000.00 66.44 233.00 2,137.80 2,028.80 -1,007.42 -1,336.89 5,944,596.38 557,392.74. 0.00 -1,007.42 3,018.00 66.44 233.00 2,145.00 2,036.00 -1,017.35 -1,350.07 5,944,586:35 557,379.64 0.00 -1,017.35 10 3/4" Csg @ 3018ft M D, 2145ft TVD - 785ft FSL & 3841ft FEL -Sec 35 - T11 N - R10E - T3+550 -10 3/4" 3,100.00 66.44 233.00 2,177.78 2,068.78 -1,062.59 -1,410.10 5,944,540.65 557,319.97 0.00 -1,062.59 3,157.52 66.44 233.00 2,200.77 2,091.77 -1,094.32 -1,452.21 5,944,508.60 557,278.12 0.00 -1,094.32. Continue Turn @ 4.5°/100ft , 3158ft MD, 2200ft TVD 3,200.00 66.12 235.06 2,217.86 2,108.86 -1,117.16 -1,483.68 5,944,485.51 557,246.83 4.50 -1,117.16 3,300.00 65.49 239.94 2,258.86 2,149.86 -1,166.16 -1,560.58 5,944,435.92 557,170.32 4.50 -1,166.16 3,400.00 65.01 244.87 2,300.74 2,191.74 -1,208.21 -1,641.03 5,944,393.25 557,090.21 4.50 -1,208.21 3,500.00 64.70 249.83 2,343.25 2,234.25 -1,243.06 -1,724.54 5,944,357.75 557,006.99 4.50 -1,243.06 3,600.00 64.56 254.81 2,386.12 2,277.12 -1,270.49 -1,810.58 5,944,329.65 556,921.16 4:50- -1,270:49 3,700.00 64.58 259.79. 2,429.09 2,320.09 -1,290.34 -1,898.65 5,944,309.12 556,833.27 4.50 -1,290.34 Min Inc Du ring Turn - 64.6°, 3700ft MD, 2429ft TVD 3,800.00 64.77 264.77 2,471.89 2,362.89 -1,302.47 -1,988.18 5,944,296.29 556,743.84 4.50 -1,302.47 3,900.00 65.12 269.72 2,514.25 2,405.25 -1,306.82 -2,078.62 5,944,291.23 556,653.44 4.50 -1,306.82 4,000.00 65.64 274.63 2,555.93 2,446.93 -1,303.36 -2,169.43 5,944,293.98 556,562.62 4.50 -1,303.36 4,100.00 66.32 279.51 2,596.66 2,487.66 -1,292.11 -2,260.04 5,944,304.53 556,471.93 4.50 -1,292.11 4,116.00 66.44 280.28 2,603.07 2,494.07 -1,289.60 -2,274.48 5,944,306.93 556,457.47 4.50 -1,289.60 Sail @ 66.4°Inc 8~ 280°Azi : 4116ft MD, 2603ft TVD 4,200.00 66.44 280.28 2,636.65 2,527.65 -1,275.85 -2,350.24 5,944,320.08. 556,381.61 0.00 -1,275.85 4,300.00 66.44 280.28 2,676.62 2,567.62 -1,259.49 -2,440.43 5,944,335.74 556,291.31 0.00 -1,259.49 4,400.00 66.44 280.28 2,716.59 2,607.59 -1,243.13 -2,530.62 5,944,351.39 556,201.00 0.00 -1,243.13 4,500.00 66.44 280.28 2,756.56 2,647.56 -1,226.77 -2,620.82 5,944,367:05 556,110.69 0.00 -1,226.77 4,545.89 66.44 280.28 2,774.91 2,665.91 -1,219.27 -2,662.20 5,944,374.23 556,069.25 0.00 -1,219.27 Continue Build/Turn @ 5°/100ft , 4546ft MD, 27 75ft TVD 4,600.00 66.09 283.21 2,796.69 2,687.69 -1,209.18 -2,710.69 5,944,383.93 556,020.69 5.00 -1,209.18 4,700.00 65.59 288.66 2,837.65 2,728.65 -1,184.15 -2,798.38 5,944,408:28 555,932.81 5.00 -1,184.15 4,700.85 65.58 288.71 2,838.00 2,729.00 -1,183.90 -2,799.11 5,944,408:52 555,932.08 5.11 -1,183.90 Ugnu C 4,800.00 65.28 294.15 2,879.25 2,770.25 -1,150.97 -2,883.02 5,944,440.79 555,847.93 5.00 -1,150.97 4,900.00 65.18 299.66 2,921.17 2,812.17 -1,109.91 -2,963.95 5,944,481.22 555,766.69 5.00 -1,109.91 5,000.00 65.28 305.16 2,963.10 2,854.10 -1,061.26 -3,040.56 5,944,529.26 555,689.71 5.00 -1,061.26 5,100.00 65.58 310.65 3,004.71 2,895.71 -1,005.41 -3,112.27 5,944,584.55 555,617.57 5.00 -1,005.41 5,193.38 66.03 315.75 3,043.00 2,934.00 -947.12 -3,174.33 5,944,642.34 555,555.06 5.00 -947.12 Ugnu B 5,200.00 66.07 316.11 3,045.69 2,936.69 -942.78. -3,178.54 5,944,646.66 555,550.82 4.98 -942.78 5,300.00 66.76 321.51 3,085.72 2,976.72 -873.84 -3,238.86 5,944,715.12 555,489.98 5.00 -873.84 5,400.00 67.63 326.85 3,124.51 3,015.51 -799.12 -3,292.76 5,944,789.41 555,435.49 5.00 -799.12 5,414.46 67.77 327.62 3,130.00 3,021.00 -787.87 -3,300.00 5,944,800.60 555,428.17 5.01 -787.87 Ugnu A 5,500.00 68.67 332.12 3,161.76 3,052.76 -719.19 -3,339.85 5,944,868.96 555,387.79 5.00 -719.19 5,600.00 69.87 337.31 3,197.18 3,088.18 -634.65 -3,379.76 5,944,953.18 555,347.23 5.00 -634.65 5,655.66 70.61 340.16 3,216.00 3,107.00 -585.84 -3,398.75 5,945,001.83 555,327.86 5.00 -585.84 K13 4/10/2006 10:38:03AM Page 5 of 10 COMPASS 2003.11 Build 50 ORIGINAL ` ~ ~ ~ Halliburton Ener Services ~ ~ : ~ ~ -.- - 9Y - CC3110001PI"11I1: S Pl i hi R t G , _ ; ,, ann ng epor - eograp c Alaska Sperry Orillrng Serviass Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk} TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-170 Design: 1J-170 (wp05) Planned Survey 1J-170 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) lft) (°i100ft) (ft) 5,700.00 71.22 342.42 3,230.50 3,121.50 -546.15 -3,412.19 5,945,041.41 555,314.11. 5.00 -546.15 5,800.00 72.71 347.44 3,261.47 3,152.47 -454.37 -3,436.89 5,945,132.99 555,288.70 5.00 -454.37 5,900.00 74.32 352.37 3,289.86 3,180.86 -360.00 -3,453.67 5,945,227.22 555,271.19 5.00 -360.00 6,000.00 76.04 357.23 3,315.45 3,206.45 -263.76 -3,462.41 5,945,323.38 555,261.70 5.00 -263.76 6,053.32 77.00 359.79 3,327.88 3,218.88 -211.93 -3,463.75 5,945,375.19 555,259.95 5.00 -211.93 Sail @ 77°I nc 8: 359.°Azi : 6053ft M D, 3328ft TVD 6,100.00 77.00 359.79 .3,338.38 3,229.38 -166.44 -3,463.92 5,945,420.67 555,259.43 0.00 -166.44 6,138.32 77.00 359.79 3,347.00 3,238.00 -129.10 -3,464.05 5,945,458.00 555,259.00 0.00 -129.10 Build @ 0.8°/100ft to 80° lint - 6138ft MD, 3347ft TVD - Wsak D -1J-170 T1 Dtop (wp05) 6,200.00 77.50 359.79 3,360.61 3,251.61 -68.95 -3,464.28 5,945,518.15 555,258.31 0.80 -68.95 6,300.00 78.30 359.79 3,381.58 3,272.58 28.83 -3,464.63 5,945,615.91 555,257.19 0.80 28.83 6,347.21 78.68 359.79 3,391.00 3,282.00 75:09 -3,464.80 5,945,662.17 555,256.66 0.80 75.09 Wsak C 6,400.00 79.10 359.79 3,401.17 3,292.17 126.89 -3,464.99 5,945,713.95 555,256.07 0.80 126.89 6,500.00 79.91 359.79 3,419.38 3,310.38 225.22 -3,465.35 5,945,812.27 555,254.94 0.80 225.22 6,511.32 80.00 359.79 3,421.36 3,312.36 236.36 -3,465.39 5,945,823.41 555,254.81 0.81 236.36 Turn @ 3°/100ft, 6511ft MD, 3421ft TVD 6,583.87 80.00 2.00 3,433.95 3,324.95 307.79 -3,464.28 5,945,894.84 555,255.37 3.00 307.79 Sail @ 80°In c & 2°Azi : 6584ft MD, 3434ft TVD - Wsak B 6,600.00 80.00 2.00 3,436.76 3,327.76 323.67 -3,463.72 5,945,910.72 555,255.80 0.00 323.67 6,700.00 80.00 2.00 3,454.12 3,345.12 422.09 -3,460.29 5,946,009.16 555,258.47 0.00 422.09 6,785.68 80.00 2.00 3,469.00 3,360.00 506.42 -3,457.34 5,946,093.50 555,260.76 0.00 506.42 Wsak A4 6,800.00 80.00 2.00 3,471.49 3,362.49 520.51 -3,456.85 5,946,107.59 555,261.14 0.00 520.51 6,900.00 80.00 2.00 3,488.85 3,379.85 618.93 -3,453.41 5,946,206.03 555,263.81 0.00 618.93 7,000.00 80.00 2.00 3,506.22 3,397.22 717.35 -3,449.98 5,946,304.46 555,266.48 0.00 717.35 7,100.00 80.00 2.00 3,523.58 3,414.58 815.78 -3,446.54 5,946,402.90 555,269.15 0.00 815.78 7,113.93 80.00 2.00 3,526.00 3,417.00 829.49 -3,446.06 5,946,416.61 555,269.52 0.00 829.49 Wsak A3 7,200.00 80.00 2.00 3,540.95 3,431.95 914.20 -3,443.10 5,946,501.33 555,271.81 0.00 914.20 7,300.00 80.00 2.00 3,558.31 3,449.31 1,012.62 -3,439.67 5,946,599.77. 555,274.48 0.00 1,012.62 7,400.00 80.00 2.00 3,575.67 3,466.67 1,111.04 -3,436.23 5,946;698.20 555,277.15 0.00 1,111.04 7,500.00 80.00 2.00 3,593.04 3,484.04 1,209.46 -3,432.79 5,946,796.64 .555,279.82 0.00 1,209.46 7,555.87 .80.00 2.00 3,602.74 3,493.74 1,264.44. -3,430.87 5,946,851.63 555,281.31 0.00 1,264.44 Continue Build @ 4°/100ft , 7556ft MD, 3603ft TVD 7,600.00 81.76 2.00 3,609.73 3,500.73 1,307.99 -3,429.35 5,946,895.18 555,282.49 4.00 1,307.99 7,680.87 85.00 2.00 3,619.05 3,510.05 1,388.26 -3,426.55 5,946,975.47 555,284.67 4.00 1,388.26 7 5/8" Csg @ 7681ft M D, 3619ft TVD - 3190ft FSL & 635ft FE L Sect 34 - T 11 N - R10E -Sail @ 85° - Wsak A2 - 7 5/8" -1J-170 DD Poly @ 95% 7,700.00 85.00 2.00 3,620.72 3,511.72 1,407.31 -3,425.88 5,946,994.52 555,285.19 0.00 1,407.31 7,700.87 85.00 2.00 3,620.79 3,511.79 1,408.17 -3,425.85 5,946,995.38 555,285.21 0.00 1,408.17 Build @ 4°/1 00ft, 7700ft MD, 3620ft TVD -Conti nue GeoSteer in Upper Lobe A2 Sand 7,800.00 86.86 5.51 3,627.83 3,518.83 1,506.82 -3,419.37 5,947,094.07 555,290.92 4.00 1,506.82 7,900.00 88.75 9.04 3,631.66 3,522.66 1,605.92 -3,406.72 5,947,193.26 555,302.79 4.00 1,605.92 7,981.69 90.30 11.91 ' 3,632.33 3,523.33 1,686.24 -3,391.87. 5,947,273.67 555,317.02 4.00 1,686.24 8,000.00 90.30 11.91 3,632.23 3,523.23 1,704.15 -3,388.09 5,947,291.62 555,320.66 0.00 1,704.15 4/10/2006 10:38:03AM Page 6 of 10 COMPASS 2003.11 Build 50 OR161NAL • Halliburton Ener Services 9Y Ct~11~3CQPI'1II1 S Pl i R hi t G ~~~ ~ °~ ~• ann ng epor - eograp c Alaska Sperrry E1rilUng Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1J-170 Design: 1J-170 (wp05) Planned Survey 1J-170 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 8,100.00 90.30 11.91 3,631.71 3,522.71 1,802.00 -3,367.45 5,947,389.61 555,340.54 0.00 1,802.00 8,200.00 90.30 11.91 3,631.18 3,522.18 .1,899.84 -3,346.80 5,947,487.60 555,360.42 0.00 1,899.84 8,242.46 90.30 11.91 3,630.96 3,521.96 1,941.39 -3,338.03 5,947,529.22 555,368.86 0.00 1,941.39 8,263.25 89.47 11.91 3,631.00 3,522.00 1,961.73 -3,333.74 5,947,549.58 555,372.99 4.00 1,961.73 1J-170 T2 (wp05) 8,300.00 89.45 10.81 3,631.35 3,522.35 1,997.76 -3,326.51 5,947,585.67 555,379.95 3.00 1,997.76 8,400.00 89.40 7.81 3,632.35 3,523.35 2,096.42 -3,310.34 5,947,684.45 555,395.35 3.00 2,096.42 8,402.98 89.40 7.72 3,632.38 3,523.38 2,099.37 -3,309.93 5,947,687.40 555,395.73 3.00 2,099.37 8,500.00 89.40 7.72 3,633.40 3,524.40 2,195.51 -3,296.90 5,947,783.63 555,408.00 0.00 2,195.51 8,509.45 89.40 7.72 3,633.50 3,524.50 2,204.88 -3,295.63 5,947,793.00 555,409.20 0.00 2,204.88 1J-170 T3 (wp05) 8,600.00 90.08 4.53 3,633.91 3,524.91 2,294.90 -3,285.97 5,947,883.08 555,418.16 3.60 2,294.90 8,700.00 90.84 1.01 3,633.10 3,524.10 2,394.76 -3,281.14 5,947,982.97 555,422.21 3.60 2,394.76 8,783.80 91.48 358.06 3,631.40 3,522.40 2,478.53 -3,281.81 5,948,066.72 555,420.88 3.60 2,478.53 8,800.00 91.48 358.06 3,630.99 3,521.99 2,494.72 -3,282.36 5,948,082.90 555,420.21 .0.00 2,494.72 8,877.20 91.48 358.06 3,629.00 3,520.00 2,571.84 -3,284.97 5,948,160.00 555,417.00 0.00 2,571,84 1J-170 T4 (wp05) 8,900.00 91.07 358.26 3,628.49 3,519.49 2,594.63 -3,285.70 5,948,182.78 555,416.09 2.00 2,594.63 8,954.40 90.09 358.74 3,627.95 3,518.95 2,649.01 -3,287.13 5,948,237.14 555,414.24 2.00 2,649.01 9,000.00 90.09 358.74 3,627.88 3,518.88 2,694.59 -3,288.13 5,948,282.71 555,412.88 0.00 2,694.59 9,100.00 90.09 358.74 3,627.73 3,518.73 2,794.57 -3,290.34 5,948,382.66 555,409.90 0.00 2,794.57 9,200.00 90.09 358.74 3,627.58 3,518.58 2,894.55 -3,292.54 5,948,482.61 555,406.91 0.00 2,894.55 9,300.00 90.09 358.74 3,627.43 3,518.43 2,994.52 -3,294.75 5,948,582.55 555,403.93 0.00 2,994.52 9,400.00 90.09 358.74 3,627.28 3,518.28 3,094.50 -3,296.95 5,948,682.50 555,400.95 0.00 3,094.50 9,500.00 90.09 358.74 3,627.13 3,518.13 3,194.47 -3,299.15 5,948,782.44 555,397.96 0.00 3,194.47 9,600.00 90.09 358.74 3,626.98 3,517.98 3,294.45 -3,301.36 5,948,882.39 555,394.98 0.00 3,294.45 9,700.00 90.09 358.74 3,626.83 3,517.83 3,394.42 -3,303.56 5,948,982.33 555,392.00 0.00 3,394.42 9,800.00 90.09 358.74 3,626.67 3,517.67 3,494.40 -3,305.77 5,949,082.28 555,389.01 0.00 3,494.40 9,900.00 90.09 .358.74 3,626.52 3,517.52 3,594.38 -3,307.97 5,949,182.23 555,386.03 0.00 3,594.38 10,000.00 90.09 358.74 3,626.37 3,517.37 3,694.35 -3,310.18 5,949,282.17 555,383.04. 0.00 3,694.35 10,100.00 90.09 358.74 3,626.22 3,517.22 3,794.33 -3,312.38 5,949,382.12 555,380.06 0.00 3,794.33 10,200.00 90.09 358.74 3,626.07 3,517.07 3,894.30 -3,314.59 5,949,482.06 555,377.08 0.00 3,894.30 10,300.00 90.09 358.74 3,625.92 3,516.92 3,994.28 -3,316.79 5,949,582.01 555,374.09 0.00 3,994.28 10,400.00 90.09 358.74 3,625:77 3,516.77 4,094.25 -3,318.99 5,949,681.95 555,371.11 0.00 4,094.25 10,500.00 90.09 358.74 3,625.62 3,516.62 4,194.23 -3,321.20. 5,949,781.90 555,368.13 0.00 4,194.23 10,600.00 90.09 358.74 3,625.47 3,516.47 4,294.20 -3,323.40 5,949,881.85 555,365.14 0.00 4,294.20 10,700.00 90.09 358.74 3,625.32 3,516.32 4,394.18 -3,325.61 5,949,981.79 555,362.16 0.00 4,394.18 10,800.00 90.09 358.74 3,625.17 3,516.17 4,494.16 -3,327.81 5,950,081.74 555,359.17 0.00 4,494.16 10,900.00 90.09 358.74 3,625.02 3,516.02 4,594.13 -3,330.02 5,950,181.68 555,356.19 0.00 4,594.13 11,000.00 90.09 358.74 3,624.87 3,515.87 4,694.11 -3,332.22 5,950,281.63 555,353.21 0.00 4,694.11. 11,100.00 90.09 358.74 3,624.72 3,515.72 4,794.08 -3,334.43 5,950,381.57 555,350.22 0.00 4,794.08 11,200.00 90.09 358.74 3,624.57 3,515.57 4,894.06 -3,336.63 5,950,481.52 555,347.24 0.00 4,894.06 11,300.00 90.09 358.74 3,624.42 3,515.42 4,994.03 -3,338.83 5,950,581.47 555,344.26 0.00 4,994.03 11,400.00 90.09 358.74 3,624.27 3,515.27 5,094.01 -3,341.04 5,950,681.41 555,341.27 0.00 5,094.01 11,500.00 90.09 358.74 3,624.12 3,515.12 5,193.98 -3,343.24 5,950,781.36 555,338.29 0.00 5,193.98 11,576.68 90.09 358.74 3,624.00 3,515.00 5,270.65 -3,344.93 5,950,858.00 555,336.00 0.00 5,270.65 1J-170 T5 (wp05) 11,600.00 89.62 358.73 3,624.06 3,515.06 5,293.96 -3,345.45 5,950,881.30 555,335.30 2.00 5,293.96 4/10/2006 10:38:03AM Page 7 of 10 COMPASS 2003.11 Build 50 ORIGINAL Halliburton Ener Services ~t~t'IUCPJ~`~'1f~1 S 5Y p Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-170 Survey Calculation Method: Wellbore: 1 J-170 Design: 1J-170 (wp05) Sperry drilling Services WeII Plan 1J-170.-Slot 1J-170 Planned RKB @ 109.OOft (Doyon 141 (28+81)) Planned RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Planned Survey 1J-170 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 11,611.11 89.40 358.73 3,624.16 3,515.16 5,305.07 -3,345.70 5,950,892.41 555,334.97 2.01 5,305.07 11,700.00 89.40 358.73 3,625.09 3,516.09 5,393.93 -3,347.67 5,950,981.24 555,332.30 0.00 5,393.93 11,800.00 89.40 358.73 3,626.14 3,517.14 5,493.90 -3,349.89 5,951,081.18 555,329.31 0.00 5,493.90 11,900.00 89.40 358.73 3,627:19 3,518.19 5,593.87 -3,352.11 5,951,181.12 555,326.31 0.00 5,593.87 11,976.92 89.40 358.73 3,628.00 3,519.00 5,670.77 -3,353.82 5,951,258.00 555,324.00 0.00 5,670.77 1J-170 T6 (wp 05) 12,000.00 88.94 358.73 3,628.34 3,519.34 5,693.84 -3,354.33 5,951,281.06 555,323.31 2.00 5,693.84 12,012.83 88.68 358.73 3,628.60 3,519.60 5,706.67 -3,354.61 5,951,293.89 555,322.92 2.01 5,706.67 12,100.00 88.68 358.73 3,630.61 3,521.61 5,793.79 -3,356.55 5,951,380.98 555,320.31 0.00 5,793.79 12,200.00 88.68 358.73 3,632.92 3,523.92 5,893.74 -3,358.76 5,951,480.90 555,317.31 0.00 5,893.74 12,300.00 88.68 358.73 3,635.22 3,526.22 5,993.69 -3,360.98 5,951,580.82 555,314.32 0.00 5,993.69 12,377.24 88.68 358.73 3,637.00 3,528.00 .6,070.89 -3,362.70 5,951,658.00 555,312.00 0.00 6,070.89 1J-170 T7 (wp05) 12,400.00 88.21 358.56 3,637.62 3,528.62 6,093.63 -3,363.23 5,951,680.73 555,311.28 2.20 6,093.63 12,481.16 86.53 357.95 3,641.34 3,532.34 6,174.67 -3,365.70 5,951,761.74 555,308.19 2.20 6,174.67 12,500.00 86.53 357.95 3,642.49 3,533.49 6,193.46 -3,366.37 5,951,780.52 555,307.37 0.00 6,193.46 12,508.50 86.53 357.95 3,643.00 3,534.00 6,201.94 -3,366.67 5,951,789.00 555,307.00 0.00 6,201.94 TD @ 12508ft M D, 3643ft TVD : 2724ft FSL & 570ft FEL -Sec 27 - T11 N - R10E - 41/2" -1J-170 T8 Toe (wp05) 4/10/2006 10:38:03AM Page 8 of 10 COMPASS 2003.11 Build 50 ORIGIN:4t. ~ '` Halliburton Ener Services ~ gv ~ ~ Cc~nc~cc~~h~~li s Pl i R hi t G _. . ~.~ ~ - - - ann ng c epor - eograp kiaska Sperry tX~lling Services Database: [DM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1J-170 Design: 1J-170 (wp05) Geologic Targets 1J-170 TVD ~f~a~~e~~t ~d~r~;>y +Nl-S +EI-W Northing Easting (ft) ~~ ~~~a ft ft (ft) (ft) 3,624.00 1J-170 T5 {wp05} 5,270.65 -3,344.93 5,950,858.00 555,336.00 - Point 3,619.05 1J-170 DD Poly ca 95°J° 1,388.26 -3,426.55 5,946,975.47 555,284.67 - Polygon Point 1 -50.00 0.39 5,946,975.47 555,234.67 Point 2 -49.31 20.30 5,946,995.38 555,235.21 Point 3 -15.33 298.36 5,947,273.67 555,267.02 Point 4 38.51 553.52 5,947,529.22 555,318.86 Point 5 42.80 573.86 5,947,549.59 555,322.99 Point 6 66.62 711.50 5,947,687.40 555,345.73 Point 7 80.91 817.00 5,947,793.00 555,359.20 Point 8 94.73 1,090.65 5,948,066.72 555,370.88 Point 9 91.57 1,183.97 5,948,160.00 555,367.00 Point 10 89.42 1,261.13 5,948,237.14 555,364.24 Point 11 31.61 3,882.77 5,950,858.00 555,286.00 Point 12 30.85 3,917.19 5,950,892.41 555,284.97 Point 13 22.73 4,282.89 5,951,258.00 555,274.00 Point 14 21.93 4,318.80 5,951,293.89 555,272.92 Point 15 13.85 4,683.01 5,951,658.00 555,262.00 Point 16 10.85 4,786.79 5,951,761.74 555,258.19 Point 17 9.87 4,814.06 5,951,789.00 555,257.00 Point 18 109.88 4,813.28 5,951,789.00 555,357.00 Point 19 110.85 4,786.01 5,951,761.74 555,358.19 Point 20 113.86 4,682.23 5,951,658.00 555,362.00 Point 21 121.94 4,318.02 5,951,293.89 555,372.92 Point 22 122.74 4,282.11 5,951,258.00 555,374.00 Point 23 130.86 3,916.42 5,950,892.41 555,384.97 - Point 24 131.62 3,881.99 5,950,858.00 555,386.00 Point 25 189.42 1,260.35 5,948,237.14 555,464.24 Point 26 191.58 1,183.19 5,948,160.00 555,467.00 Point 27 194.73 1,089.87 5,948,066.72 555,470.88 Point 28 180.92 816.22 5,947,793.00 555,459.20 Point 29 166.62 710.72 5,947,687.40 555,445.73 Point 30 142.81 573.08 5,947,549.59 555,422.99 Point 31 138.52 552.74 5,947,529.22 555,418.86 Point 32 84.68 297.58 5,947,273.67 555,367.02 Point 33 50.70 19.52 5,946,995.38 555,335.21 Point 34 50.00 -0.39 5,946,975.47 555,334.67 3,643.00 1J-17fl T8 Toe {wp05} 6,201.94 -3,366.67 5,951,789.00 555,307.00 - Point 3,347.00 1J-170 T1 Dtop {p05} -129.10 -3,464.05 5,945,458.00 555,259.00 - Point 3,628.00 1J-170 T6 (wp05} 5,670.77 -3,353.82 5,951,258.00 555,324.00 - Point 3,631.00 1J-170 T2 (tvp45} 1,961.73 -3,333:74 5,947,549.58 555,372.99 - Point 3,633.50 1J-170 T3 {wp05} 2,204.88 -3,295:63 5,947,793.00 555,409.20 - Point 3,637.00 1J-170 T7 (wDS} 6,070.89 -3,362.70 5,951,658.00 555,312.00 - Point 3,629.00 1J-176 T4 {wp05} 2,571.84 -3,284.97 5,948,160.00 555,417.00 4/10/2006 10:38:03AM Page 9 of 10 o~~~~~ COMPASS 2003.11 Build 50 ~Q110CUP`~"1~~1~?S Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-170 Wellbore: 1J-170 Design: 1J-170 (wp05) - Point - Halliburton Energy Services ~ ~~ ~.- n ~d_,~~~,~~ ~ ~~~ Planning Report -Geographic - -- - sperry t7riilling se~rviees Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 80.00 80.00 20 20 3,018.00 2,145.00 10-3/4 13-1/2 7,680.87 3,619.05 7-518 9-7/8 12,508.49 3,643.00 4-1/2 6-3/4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ft) (ft) Name .1,660.56 47.19. 233.00 1,521..00.. -297.68 -395.04 Base Perm. 1,831.32 51.76 233:00 1,634.00 -374.68 -497.22 T3 2,470.10 66.44 233.00 1,926.00 -715.10 -948.98 K15 3,018.00 66.44 233.00 2,145.00 -1,017.35 -1,350.07 T3+550 4,700.85 65.58 288.71 2,838.00 -1,183.90 -2,799.11 Ugnu C 5,193.38 66.03 315.75 3,043.00 -947.12 -3,174.33 Ugnu B 5,414.46 67.77 327.62 3,130.00 -787.87 -3,300.00 Ugnu A 5,655.66 70.61 340.16 3,216.00 -585.84 -3,398.75 K13 6,138.32 77.00 359.79 3,347.00 -129.10 -3,464.05 Wsak D 6,347.21 78.68 359.79 3,391.00 75.09 -3,464.80 Wsak C 6,583.87 80.00 2.00 3,433.96 307.80 -3,464.28 Wsak B 6,785.68 80.00 2.00 3,469.00 506.42 -3,457.34 Wsak A4 7,113.93 80.00 2.00 3,526.00 829.49 -3,446.06 Wsak A3 7,680.87 85.00 2.00 3,619.05 1,388.26 -3,426.55 Wsak A2 4/10/2006 10:38:03AM Page 10 of 10 COMPASS 2003.11 Build 50 ~~t~~a~ r~ ConocPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-170 1J-170 1J-170 (wp05) Anticollision Report 10 April, 2006 • sp~rir~ t'~r~l~n~g s~~c ORIGINAL SURVEY PROGRAM NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-170 ConocePhillips Alaska (Kuparuk) -- "-- Dale: 200G0410T00:00:00 Validated: Yes Version: ANTI-COLLJSION SETTINGS Ground Level: 81 00 Drilling & Wells Interpola0on Method: MD Interval: SOSfations . +NIS +EI-W Northing Easting Latiftude Longitude Slot . West Sak Depth From Dep[h To Survey/Plan Tool Depth Range From: 28.00 To 12508.50 0.00 0.00 5945614.10 558721.61 70°15'43.258N 149°31'31.o65W 1J-170 28.00 800.00 1J-170 (wp05) CSCYRO-SS Maximum Range:1448.04998689013 Calculation Method: Minimum Curvature 800.00 12508.50 1J-170 (wp05) MWD+IFR-AK-CAZSC Reference: Plan: 1J-170 (wp05) Error System: ISCWSA Scan Method: Trev. Cylinder North Error Surtace: Elliptical Conic 1J-166 WSP-20 warning Method: Rules Based 1J-159 1J-164 ~~ WSP-04 1J-160 (wp01) ~ tl `~ ~ ~ ~ - 30 \ ` ~ ~ ' Plan 1J-118 w 01 330 30 ~ 1J-115 (wp02) ~ ~ ( P ) ~ /~ ~ ',/ : i ~ WSP-05 - i 1J-173 Pilot w 06 1J-162 (wp03.1-NoRh Heel) ~" ~~ ~ ~ ~ 1~ ~' ( P ) 300 60 300 1 J-168 _ 1 270 ~~ ~, \ , + a r ( ,! _~~ ~ ~= /. ~ ~ .rte ~ i k, /~ ~- ~ ~ ~ul~ i i-°I ' i~60 ~ i ,' 1J-120 (wp01) , 1J-23 Pilot (wp01) -' 1 1 ' ~ ~ , ~ - =, / ~ Vii- '~ , - ~-' WSP-06 270 90 ~ . ~ ~ . !- 1J-122 (wp02) `` t'`` i ~ y~,~ 4 --'.~ 4~';ga - - - WSP-07 ( 1J-127 (wp03) 1 240 120 a _ WSP-08 20 ` 1J-129 (wp02) 1J-130 (wp02) 25 ~'' 210 150 12 12o From Colour To MD 30 180 % ~ 28 250 250 500 Travelling Cylinder Azimuth (TFO+AZI) ~°] vs Centre to Centre Separation ]15 tt/in] 0.`~~ ` `. i i 500 750 750 1000 SECTION DETAILS ~ ~~~. ( "~, /~ \ ,/ ' i ~ 1000 1250 1250 "°' 1500 Sec MD Inc Azi TVD +NIS +EI-W DLeg TFace VSec Target 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.0000 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.0000 O.oO x~._-~ ' 210 '~ ; 150 1J-132 (Wp02) 1500 '"""'""'" """""'""' 1750 3 700.00 10.00 233.00 697.97 -20.95 -27.81 4 1629.66 x7.19 233.00 1500.00 -28x.04 J76.94 2.50233.0000 -20.95 4.00 0.0000 -284.04 -~ 1J-174(wp01) ^~.--_ r=~ 1750 2000 5 1729.66 47.19 233.00 1567.96 -328.19 435.52 0.00 0.0000 328.19 - ~ ' y . 1 ~ ~ 2000 """"' ""~""" 2250 6 2157.52 66.44 233.00 1801.06 -542.67 -720.14 7 3157.52 66.44 233.00 2200.77 -1094.32 -1452.21 0.50 0.0000 542.67 0.00 0.0000 -1094.32 _ 8 4116.00 66.44 280.28 2603.07 -1289.60 -2274.48 4.50 99.9260 -1289.60 1J-178 W 01 i ~ ( P ) 180 2250 2500 9 4545.89 66.44 280.28 2774.91 -1219.27 -2662.20 0.00 0.0000 -1219.27 ~ \ ~ 2500 2750 10 6053.32 77.00 359.79 3327.88 -211.93 -3463.75 5.00 98.0369 -211.93 i 1J-178 (wp01) 1J-180 (wp01) 1J-182 (wp05) 2750 3000 11 6138.32 77.00 359.79 3347.00 -129.10 -3464.05 12 6511.32 80.00 359.79 3421.36 236.36 -3465.39 0.00 0.0000 -129.10 1J-170 T1 Dtop (wp04) 0.80 0.0000 236.36 3000 3250 13 6583.87 80.00 2.00 3433.95 307.79 -3464.28 14 7555.87 80.00 2.00 3602.74 1264.44 -3430.87 3.00 90.1919 307.79 0.00 0.0000 1264.44 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ft/in] 3250 3500 15 7680.87 85.00 2.00 3619.05 1388.26 J426.55 4.00 0.0000 1388.26 3500 3750 16 7700.87 85.00 2.00 3620.79 1409.17 -3425.85 0.00 0.0000 1408.17 17 7981.69 90.30 11.91 3632.33 1686.24 -3391.87 4.00 62.1189 1686.24 3750 4000 18 8242.46 90.30 11.91 3630.96 1941.39 -3338.03 0.00 0.0000 1941.39 79 8263.25 89.47 11.91 3631.00 1961.73 -3333.74 0.00179.6607 1961.73 1J-170 T2 (wp04) 4000 5000 20 8402.98 89.40 7.72 3632.38 2099.37 -3309.93 3.00 A1.0063 2099.37 5000 6000 21 8509.45 89.40 7.72 3633.50 2204.88 -3295.63 0.00 0.0000 2200.88 1J-170 T3 (wp04) 22 8783.80 91.48 358.06 3631.40 2478.53 -3281.81 3.60-77.8498 2478.53 6000 7000 23 8877.20 91.48 358.06 3629.00 2571.84 -3284.97 0.00 0.0000 2571.84 1J-170 T4 (wp04) 7000 8000 24 8950.40 90.09 358.74 3627.95 2649.01 -3287.13 2.00154.0955 2649.01 REFERENCE INFORMATION 25 11576.68 90.09 358.74 3624.00 5270.65 -3344.93 0.00 0.0000 5270.65 1J-170 T5 (wp04) 8000 9000 26 11611.11 89.40 358.73 3620.16 5305.07 -3345.70 2.00179.2722 5305.07 Coordinate (NIE) Reference: Well Plan 1J-170 -Slot 1J-170, Tme North 9000 - 1000 27 11976.92 89.40 358.73 3628.00 5670.77 -3353.82 0.00 0.0000 5670.77 1J-170 T6 (wp04) Vertical (TVD) Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 )) 28 12012.83 88.68 358.73 3628.60 5706.67 -3354.61 2.00179.9686 5706.67 Section (VS) Reference: Slot -1J-170(O.OON, O.OOE) 10000 1100 29 12377.24 88.68 358.73 3637.00 6070.89 -3362.70 0.00 0.0000 6070.89 1J-170 T7 (wp04) Measured Depth Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) 30 12481.16 86.53 357.95 3641.34 6174.67 -3365.70 2.20160.2377 6174.67 Calculation Method: Minimum Curvature 11000 ~. 1200 31 12508.50 86.53 357.95 3643.00 6201.94 -3366.67 0.00 0.0000 6201.94 1J-170 T8 Toe (wp04) Cc~r~oea~'h i lti ~s ,~.(~tska Halliburton Energy Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan iJ-170 Well Error: O.OOft Reference Wellbore 1J-170 Reference Design: 1J-170 (wp05) Local Co-ordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: ~OL~i~~ !~__~.-~ ~ _. per~r+y E-teitting Services Well Plan 1J-170 -Slot 1J-170 Planned RKB @ 109.OOft (Doyon 141 (28+81)) Planned RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-170 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen 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 1,448.05ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 4/10/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-170 (wp05) (1J-170) CB-GYRO-SS Camera based gyro single shot 800.00 12,508.50 1J-170 (wp05) (1J-170) 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 4/10/2006 10:43:18AM Page 2 of 6 COMPASS 2003.11 Build 50 ~I~~~~.. CQrtQ~ hii~~ r'~.I<3ska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error. O.OOft Reference Well: Plan 1J-170 Well Error: O.OOft Reference Wellbore 1J-170 Reference Design: 1J-170 (wp05) Halliburton Energy Sen Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db 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) j Kuparuk 1J Pad 1J-10 - 1J-10 - 1J-10 8,270.42 5,650.00 239.27 121.76 120.89 Pass -Major Risk 1J-159 - 1J-159 - 1J-159 395.96 400.00 239.18 8.75 230.44 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 395.96 400.00 239.18 8.75 230.44 Pass -Major Risk 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 395.96 400.00 239.18 8.75 230.44. Pass -Major Risk 1J-159 - iJ-159 L1 P62 - 1J-159 L1 PB2 395.96 400.00 239.18 8.75 230.44 Pass -Major Risk 1J-159 - 1J-159 L2 - 1J-159 L2 395.96 400.00 239.18 8.75 230.44 Pass -Major Risk 1J-159 - 1J-159 P61 - 1J-159 PB1 395.96 400.00 239.18 8.75 230.44 Pass -Major Risk 1J-164 - 1J-164 - 1J-164 397.92 400.00 120.59 8.78 111.81 Pass -Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 397.92 400.00 120.59 8.78 111.81 Pass -Major Risk 1J-164 - 1J-164 L2 - 1J-164 L2 397.92 400.00 120.59 8.78 111.81 Pass -Major Risk 1J-164 - 1J-164 L2 PB1 - 1J-164 L2 PB1 397.92 400.00 120.59 8.78 111.81 Pass -Major Risk 1J-166 - 1J-166 - 1J-166 398.54 .400.00. 80.12 8.79. . 71.33 Pass -Major Risk iJ-166 - 1J-166 L1 - 1J-166 L1 398.54 400.00 80.12 8.79 71.33 Pass -Major Risk 1J-166 - 1J-166 L1 PB1 - 1J-166 L1 PB1 398.54 400.00 80:12 8.79 71.33 Pass -Major Risk iJ-166 - 1J-166 L2 - 1J-166 L2 398.54 400.00 80.12 8.79 71.33 Pass -Major Risk 1J-166 - 1J-166 L2 PB1 - 1J-166 L2 PB1 398.54 400.00 80.12. 8.79 71.33 Pass -Major Risk 1J-168 - 1J-168 - 1J-168 548.74 550.00 41.18 11.60 29.58 Pass -Major Risk 1J-168 - 1J-168 L1 - 1J-168 L1 548.74 550.00 41.18 11.60 29.58 Pass -Major Risk 1J-168 - iJ-168 L2 - 1J-168 L2 548.74 550.00 41.18 11.60 29.58 Pass -Major Risk 1J-168 - 1J-168 L2 PB1 - 1J-168 L2 PB1 548.74 550.00 41.18 11.60 29.58 Pass -Major Risk Plan iJ-115 -Plan 1J-115 - 1J-115 (wp02) 346.17 350.00 202.77 7.52 195.25 Pass -Major Risk Plan 1J-118 -Plan 1J-118 -Plan 1J-118 (wp01) 347.55 350.00 166.99 7.00 159.99 Pass -Major Risk Plan 1J-120 -Plan 1J-120 - 1J-120 (vvp01) 347.86 350.00 151.86 7.01 144.86 Pass -Major Risk Plan 1J-122 -Plan 1J-122 - 1J-122 (wp02) 347.22 350.00 147.02 7.64 139.37 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 E Lat - 1J-23 E 335.07 350.00 147.70 7.30 140.39 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 Pilot - 1J-23 Pil 335.07 350.00 147.70 7.30 140.39 Pass -Major Risk Plan 1 J-123 Kuparuk. Prelim - 1 J-23 W Lat - 1 J-23 \ 335.07 350.00 147.70 7.30 140.39 Pass -Major Risk Plan 1J-124 -Plan 1J-124 - 1J-124 (wp01) BHI 287.99 300.00 151.93 6.22 145.70 Pass -Major Risk Plan 1J-127 -Plan 1J-127 - 1J-127 (wp03) 384.48 400.00 177.93 8.38 169.54 Pass -Major Risk Plan 1J-127 -Plan 1J-127 L1 - 1J-127 Li (wp03) 384.48 400.00 177.93 8.38 169.54 Pass.- Major Risk Plan 1 J-127 -Plan 1J-127 L2 - 1 J-127 L2 (wp03) 384.48 400.00 177.93 8.38 169.54 Pass -Major Risk Plan 1J-129 (Q13 Phase 2) -Plan 1J-129 - 1J-129 i 336.73 350.00 202.98 7.44 195.53 Pass -Major Risk Plan 1J-130 -Plan 1J-130 - iJ-130 (wp02) 336.86 350.00 217.28 7.44 209.83 Pass -Major Risk Plan 1J-132 (Q12 Phase 2) -Plan 1J-132 - 1J-132 i 337.11 350.00 248.30 7.34 240.96 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispos 9,893.20 5,721.67 556.22 170.18 402.92 Pass -Major Risk Plan 1J-156 - 1J-156 - 1J-156 (wp04) 5,373.67 5,250.00 273.70 108.20 169.63 Pass -Major Risk Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp04) 5,373.67 5,250.00 273.70 108.19 169.63 Pass -Major Risk Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp04) 5,373.67 5,250.00 273.70 108.19 169.63 Pass -Major Risk Plan 1J-158 - 1J-158 - 1J-158 (wp03) 348.79 350.00 260.32 7.40 252.91 Pass -Major Risk Plan 1J-160 -Plan iJ-160 - 1J-160 (wp01) BHI 348.13 350.00 220.98 7.55 213.43 Pass -Major Risk Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel) 349.59 350.00 160.91 7.42 153.49 Pass -Major Risk Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) 349.59 350.00 160.91 7.31 153.60 Pass -Major Risk Plan 1J-162 - 1 J-162 L2 - 1 J-162 L2 (wp3.1) 349.59 350.00 160.91 7.31 153.60 Pass -Major Risk Plan 1J-170 - 1J-170 L1 - 1J-170 L1 (wp05) 6,599.97 6,599.97 0.34 2.73 -2.03 FAIL - No Errors Plan 1J-170 - 1J-170 L2 - 1J-170 L2 (wp05) 6,199.96 6,199.98 1.71 4.33 -2.09 FAIL - No Errors Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E La' 688.26 700.00 55.71 15.03 40.68 Pass -Major Risk Plan 1J-173 Kuparuk - 1 J-73 Kuparuk - 1 J-73 W La 688.26 700.00 55.71 15.03 40.68 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Pilot - 1J-173 Pilot (wF 688.26 700.00 55.71 15.03 40.68 Pass -Major Risk Plan 1J-174 (Q1 Phase 2) -Plan 1J-174 - 1J-174(w 249.99 250.00 80.48 5.41 75.07 Pass -Major Risk Plan 1J-176 (Q2 Phase 2) -Plan iJ-176 - 1J-176 (v 301.01 300.00 120.61 5.98 114.63 Pass -Major Risk Plan 1J-178 (03 Phase 2) -Plan 1J-178 - 1J-178 (v 301.02 300.00 160.76 5.98 154.79 Pass -Major Risk Plan 1J-180 Q4 Phase 2 -Plan 1J-180 - 1J-180 v 301.03 300.00 200.79 5.97 194.82 Pass - Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/10/2006 10:43:18AM Page 4 of 6 COMPASS 2003.11 Build 50 • fices ~~~~~..~r t..:. ~; Sperry [>llrilling Services Well Plan 1J-170 -Slot 1J-170 Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Planned RKB @ 109.OOft (Doyon 141 (28+81)) i''~ • ~c~r~~~oP'h~l~ip-s al:~ka Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-170 Well Error: O.OOft Reference Wellbore 1J-170 Reference Design: 1J-170 (wp05) Halliburton Energy Services 4~ ~. , -~ ,,_,. Anticollision Report Sperry Dntlrng ServtCes Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan 1J-170 -Slot 1J-170 Planned RKB @ 109.OOft (Doyon 141 (28+g1)) Planned RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Summary Site Name Offset Well -Wellbore -Design Kuparuk 1J Pad Plan 1J-182 - 1J-182 - 1J-182 (wp05) Plan 1J-182 - iJ-182 L1 - 1J-182 L1 (wp05) Plan iJ-184 - 1J-184 - 1J-184 (wp09) Plan 1J-184 - iJ-184 L1 - 1J-184 L1 (wp09) WSP-04 -WSP-04 -WSP-04 WSP-05 -WSP-05 -WSP-05 WSP-06 -WSP-06 -WSP-06 WSP-07 -WSP-07 -WSP-07 WSP-08 -WSP-08 -WSP-08 WSP-20 -WSP-20 -WSP-20 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 405.37 400.00 240.60 405.37 400.00 240.60 299.99 300.00 280.54 299.99 300.00 280.54 384.22 400.00 215.45 380.38 400.00 189.85 334.50 .350.00 181.24 381.93 400.00 190.76 538.66 550.00 222.74 551.71 550.00 127.55 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) 8.75 231.85 Pass -Major Risk 8.53 232.07 Pass -Major Risk 6.60 273.94. Pass -Major Risk 6.60 273.94 Pass -Major Risk 7.86 207.59 Pass -Major Risk 9.77 180.08 Pass -Major Risk 8.52 .172.71 Pass -Major Risk 11.03 .179.73 Pass -Major Risk 23.93 199.23 Pass -Major Risk 13.66 113.90 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/10/2006 10:43:18AM Page 5 of 6 COMPASS 2003.11 Build 50 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit. Kuparuk 1J Pad Plan 1J-170 -Slot 1J-170 Plan: 1J-170 (wp05) 1/4 Mile Scan 09 April, 2006 - ~: >: periry- Drilling ervi+ces ORIGINAL 5 10000 Shown are Existing wells which appear to violat the 1320' radius surrounding the 1J-170 production one; 9375 1 E-105, 1 J-166, 1 J-168, 1 J-10 8750 1 E-126 and 1J-152 do not violate the 1/4 mile scan ~ 8125 7500 1E-126L2 1E-126L1 ` 1 E-126 _ ~ 6875 5625 5000 4375 ~_ o N 3750 `s r 0 z 3125 I ~ .. 0 1J-168 ----____ 1J-168 L1 ~ / ' ' 1J-168 L2 1J-166 L2 - - 1J-166 L1 ,' 1 1J-166 1 E105L1 1E-105L2 ~ ~ ~~ 1E-105 ~~ i 1J-170 1/4 mile at To ° 359 I _ I I 359° t 1 _. I 3 359° R 1875 I t2 I I I 1250 I I E I 625 \ I \~ i r I .It \~ f 0 1J-1701/4 mile atHee ______________,______-_ S_ --------- ~ o~ O 3`~° -625 ~tiy ~ c~ oe ~`J ~O N B N n N -1250 ._-- o 1J-152P61----- -1875 , ~C'~tIaCOPh11~~l~3S 1J-,s2 ~~ 1J-152 P62 1J-152 L1 -2500 ``_` ~~' -8750. -8125 -7500 -6875 -6250 -5625 -5000 -4375 -3750 -3125 -2500 -1875 -1250 -625 0 t ) t (1250 ft/in) Closest In Pool 1J-170 (wp05) - A sand ~` ~'F: ~~.. Closest A roach: Reference Well: 1J-17 0 wp05 Plan Qffset ell: E-105 /' Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. Depth Incl. An le TRUE Azi. TVD E + /W - 0° Comments Depth Incl. An le TRUE Azi. TVD E + /W - 0° Comments P L Min Distance POOL Min Distance (1237,42 ft) in POOL (1237.42 ft) in POOL (7571 - 12399.43 (7571 - 12399.43 MD) to 1J-170 (wp04) MD) to 1 Echo-105 Plan (8295 - 13539 1237.42 12508 86.53 357.95 3533.873 5951790 555306.5 6202.194 (8295 - 13539 MD) 13539 90.63 181.05 3530.373 5953009 555517.9 7415.865 MD) Closest Ap roach: Reference Well : 1J-17 0 wp05 ) Plan Uset ell: 1J -152 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. Depth Incl. Angle TRUE Azi. TVD E + /W(- 0° Comments Depth Incl. An le TRUE Azi. TVD E + NV - 0° Comments POOL Min Distance POOL Min Distance (2520.27 ft) in POOL (2520.27 ft) in POOL (7571 - 12399.43 (7571 - 12399.43 MD) to 1J-170 (wp04) MD) to 1J-152 (6532 - Plan (6532 - 10053 2520.27 7680 85 2 3510.105 5946976 555284.2 1388.526 10053 MD) 6550 89.12 9 3529.854 5945032 556888.1 -567.9137 MD) Closest A roach: Reference Well : 1J-17 0 w 05 Plan set ell° J -168 ~ 2osn o Coords. - Coords. - -D ctr- ASP A$P tr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS ist. Depth Incl. An le TRUE Azi. TVD E + /W - 0° Comments De th Incl. An le TRUE Azi. TVD E + /W - 0° Comments P L Min Distance POOL Min Distance (1283.3 ft) in POOL (1283.3 ft) in POOL (7571. - 12399.43 (7571 - 12399.43 MD) to 1J-170 (wp04) MD) to 1J-168 (8299 - Plan (8299 - 12995 1283,3 10634 90.09 358.74 3516.404 5949916 555363.6 4328.52 12995 MD) 10900 90.7 9.04 3473.052 5949878 554081.6 4300.795 MD) Closest A roach: Reference Well: 1J-17 0 w 05 Plan Qffset ell: -1 .~' Zn 5/ $ Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. De th Incl. An le TRUE Azi. ND E(+ /W(- 0° Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) 0° Comments POOL Min Distance POOL Min Distance (1282.29 ft) in POOL (1282.29 ft) in POOL (7571 - 12399.43 (7571 - 12399.43 MD) to 1 J-170 (wp04) j MD) to 1J-166 (6350 - Plan (6350 - 12853 1282.29 10059 90.09 358.74 3517.307 5949342 555380.8 3753.66 12853 MD) 7300 90.08 359.34 3545.786 5949391 556661.8 3792.689 MD) Closest In Pool 1J-170 (wp05) - A sand 1 '++/ ~/D7/ ~~~ Closest Approach: Reference Well: 1J-17 0 wp05 Plan ®ffset ell: 1J -10 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. Depth Incl. An le TRUE Azi. TVD E + /W - 0° Comments Depth Incl. An le TRUE Azi. ND E + /W - 0° Comments in is once POOL Min Distance (239.12 ft) in POOL (239.12 ft) in POOL (7571 - 12399.43 (7571 - 12399.43 MD) to 1 J-170 (wp04) / ~ MD) to 1J-10 (3236 - Plan (3236 - 3531 239.12 8263 89.47 11.91 3522.113 5947550 555372.5 1961.987 3531 TVDss) 5625 62.8 300.19 3306.907 5947572 555270.6 1984.818 TVDss) Closest A roach: Reference Well: 1J-17 0 w 05 Plan Offset ell: 1 E-126 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Dist. De th Incl. An le TRUE Azi. TVD E + /W - 0° Comments De th .Incl. An le TRUE Azi. ND E + /W - 0° Comments P L Min Distance POOL Min Distance (1588.21 ft) in POOL (1588.21 ft) in POOL (7571 - 12399.43 (7571 - 12399.43 MD) to 1J-170 (wp04) MD) to 1 Echo126 Plan (8200 - 12611 1588,21 12508 86.53 357.95 3533.873 5951790 555306.5 6202.194 (8200 - 12611 MD) 12611 88.98 185.82 3473.787 5952539 553907.7 6957.119 MD) ~~ 4 '>~ - ...s ~t-,,cam r 5 -~-- SGY~ ~ a su a y c~ a..~ ~..~e se.,/ ~.e,/~~~-c_ v s'iz •aG r C7 Closest In Pool 1 J-170 L1 (wp05) B-Sand ,--~ j 4~ ~ Closes t A roach: Reference Wel l: 1J-170 L1 w p05 Plan C2ffset Welt: -105 L1 Coords. - Coords. - ASP ASP 3•D ctrctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 0° Comments Depth Incl. An le TRUE Azi. TVD E + /W - 0° Comments P L Min Distance POOL Min Distance (1109.28 ft) in POOL (1109.28 ft) in POOL (6475 - 12539.85 MD) (6475 - 12539.85 MD) to 1J-170 L1 (wp04) to 1 Echo105 L1 Plan (7524 - 13529 11p9.28 12648 86.44 359.53 3415.91 5951920 555306.1 6332.202 (7524-13529 MD) 13529 90.05 180.24 3386.089 5953008 555516 7415.508 MD) Closest A roach: Reference Well : 1J-170 L1 w 05 Plan Offs etl: 1J -152 L1 w 05 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. TVD E + /W _ (0° Comments Depth Incl. An le TRUE Azi. TVD E + /W - 0° Comments POOL Min Distance POOL Min Distance (1636.13 ft) in POOL (1636.13 ft) in POOL (6475 - 12539.85 MD (6475 - 12539.85 MD) to 1J-170 L1 (wp04) to 1J-152 L1 (wp05) Plan (5517 - 1636.13 6659 82.5 3.01 3335.654 5945969 555257.3 382.4328 (5517-13244.76 MD) 5517.94 80 182 3393.562 5945889 556890.4 289.4335 13244.76 MD) Closest A roach: Reference Well : 1J-170 L1 w 05 Plan Offset Well: 1J -168 L1 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 - 0° Comments De th Incl. An le TRUE Azi. TVD E + /W _ 0° Comments P OL Min Distance POOL Min Distance (1342.82 ft) in POOL (1342.82 ft) in POOL (6475 - 12539.85 MD) (6475 - 12539.85 MD) to 1J-170 L1 (wp04) to 1J-168 L1 (7145 - Plan (7145 - 12967 1542.82 6709 83.4 4.52 3341.791 5946019 555260.1 431.9458 12967 MD) 7145 80.15 3185.22 5946152 553933.2 575.9689 MD) Closest A roach: Reference Well : 1J-170 L1 w 05 Plan fPset Welt; -166 L 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 - 0° Comments Depth Incl. An le TRUE Azi. TVD E + /W _ 0° Comments POOL Min Distance POOL Min Distance (1153.6 ft) in POOL (1153.6 ft) in POOL (6475 - 12539.85 MD) (6475 - 12539.85 MD) to 1J-170 L1 (wp04) / to 1J-166 L1 (5380 - Plan (5380 - 12952 1153.6 8259 88.74 2.36 3373.737 5947539 555547.1 1949.673 12952 MD) 5400 80.94 2.38 3389.984 5947506 556700.1 1907.465 MD) Closest A roach: Reference Well : 1J-170 L1 w 05 Plan Offset Wetl: 1J -10 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. TVD E + AN - 0° Comments De th Incl. An le TRUE Azi. TVD E + /W _ 0° Comments PO L Min Distance POOL Min Distance (209.15 ft) in POOL (209.15 ft) in POOL (6475 - 12539.85 MD) (6475- 12539.85 MD) to 1J-170 L1 (wp04) to 1 J-10 (3236 - 3531 Plan (3236 - 3531 209.15 8209 88.85 3.85 3372,683 5947489 555544.8 1899.759 TVDss) 5475 61.68 300.66 3237.638 5947505 555385.9 1917.485 TVDss) • Closest In Pool 1J-170 L1 (wp05) B-Sand Closest Ap roach: Reference Well : 1J-170 L1 w 05 Plan ffset Weil: 1-1L1 Coords. - Coords. - ASP ASP 3-D ctrctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /w - 0° Comments De th Incl. An le TRUE Azi. ND E + /W - 0° Comments P L Min Distance POOL Min Distance (1592.74 ft) in POOL (1592.74 ft) in POOL (6475 - 12539.85 MD) (6475 - 12539.85 MD) to 1J-170 L1 (wp04) to 1 Echo-126L1 Plan (7305 - 12468 1592.74 12648 86.44 359.53 3415.91 5951920 555306.1 6332.202 (7305-12468 MD) 12468 93.25 197.37 3295.642 5952699 553922.2 7116.447 MD) • • Closest in Pool 1 J-170 L2 (wp05) D-Sane-_, ~.. Closest A roach: Reference Well : 1J-170 L2 w 05 Plan Offset Well; -105L2 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 - 0° Comments De th Incl. An le TRUE Azi. TVD E + AN - 0° Comments P OL Min Distance POOL Min Distance (1040.73 ft) in POOL (1040.73 ft) in POOL (6029 - 12627.21 MD) (6029 - 12627.21 MD) to 1J-170 L2 (wp04) to 1 Echo-105L2 Plan (7258 - 13530 1{I40.73 12736 86.09 0.37 3361.078 5951979 555306.4 6391.208 (7258-13530 MD) 13530 90.68 183.62 3302.413 5953011 555427.6 7418.249 MD) Closest A roach: Reference Well : 1J-170 L2 w 05 Pian Offset ell: 1J -152 L2 w 05 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(-) 0° Comments Depth Incl. An le TRUE Azi. TVD E + /W - (0°) Comments POOL Min Distance POOL Min Distance (1490.94 ft) in POOL (1490.94 ft) in POOL (6029 - 12627.21 MD) (6029 - 12627.21 MD) to 1J-170 L2 (wp04) to 1J-152 L2 (wp05) Plan (5231 - 1496.94 7234 89.11 14.11 3289.349 5946528 555459.6 939.8766 (5231-12939.91 MD) 5231.62 76 3328.122 5946167 556905.7 567.5432 12939.91 MD) Closest A roach: Reference Well : 1J-170 L2 w p05 Plan Offset Well: J -168 L 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 + /VV - 0° Comments De th Incl. An le TRUE Azi. TVD E + /W - 0° Comments POOL Min Distance POOL Min Distance (1321.47 ft) in POOL (1321.47 ft) in POOL (6029 - 12627.21 MD) (6029 - 12627.21 MD) to 1J-170 L2 (wp04) to 1 J-168 L2 (6874 - Plan (6874 -12959 1321.47 6409 86.79 8.15 3274.863 5945725 555272.2 138.3488 12959 MD) 6875 80.66 3 3124.47 5945892 553970 315.5513 MD) Closest A roach: Reference Well : 1J-170 L2 w 05 Plan Offset Wetl: 1 66 L2 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. ND E + /W - 0° Comments Depth Incl. An le TRUE Azi. ND E + /W - 0° Comments POOL Min Distance POOL Min Distance (1041.56 ft) in POOL (1041.56 ft) in POOL (6029 - 12627.21 MD) 0 9 D) ) ? to 1J 166 L2 (5005 12994 Plan (005 1041,56 8159 89.24 6.1 3303.532 5947429 555667 1839.099 12994 MD) 5225 84.75 6.01 3335.989 5947337 556704 1739.013 MD) Closest A roach: Reference Well : 1J-170 L2 w 05 Plan Offset Well: 1J -10 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. TVD E + /W - 0° Comments De th Incl. An le TRUE Azi. TVD E + AN - 0° Comments P L Min Distance POOL Min Distance (293.76 ft) in POOL (293.76 ft) in POOL (6029 - 12627.21 MD) (6029 - 12627.21 MD) to 1 J-170 L2 (wp04) to 1 J-10 (3236 - 3531 Plan (3236 - 3531 293.76 8234 89.31 2.35 3304.485 5947504 555672 1913.876 TVDss) 5475 61.68 300.66 3237.638 5947505 555385.9 1917.485 TVDss) ;: • Closest in Pool 1J-170 L2 (wp05) D-Sand Closes t A roach: Reference Well : 1J-170 L2 w 05 Plan ffset Well: 1-126 L2 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. TVD E + /yy _ 0° Comments De th Incl. An le TRUE Azi. ND E + /W - 0° Comments P L Min Distance POOL Min Distance (1551.04 ft) in POOL (1551.04 ft) in POOL (6029 - 12627.21 MD) (6029 - 12627.21 MD) to 1J-170 L2 (wp04) to 1 E-126L2 (7105 - Plan (7105 - 12457 1551 AA 12736 86.09 0.37 3361.078 5951979 555306.4 6391.208 12457 MD) 12457 85.52 195.25 3283.327 5952698 553934.7 7115.91 MD) • `"° a0'`s/ „~A .',~"~r. .~`° =- 5i • 1J-170~rilling Hazards S~nmarv (SEE WELL PLAN AND TTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" O en Hole / 10-3/ "Casin Interval 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, Increase Gravels mud weight, use wei hted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" O en Hole / 7-5/8" Casin Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use wei hted sweeps. 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 weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" O en Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate ` Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-170 Drilling Hazards Summary prepared by Shane Cloninger 3/20/2006 1:32 PM 1 CemC,~DE Preliminary Job Design 10 3/4' Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 4/25/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 26311207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface s'3 .3 Previous Csg. < 16", 62.6# casing at 80' MD < Base of Permafrost at 1,661' MD (1,521' TVD) < Top of Tail at 2,218' MD < 10 3/4", 45.0# casing in 13 1!2" OH TD at 3,018' MD (2,145' ND) Mark of Schlumberger Schlam~erger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,218' MD. Sperry WP-05 Lead Slurry Minimum pump time: 220 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 (1661' - 80') x 3.50 (250% excess) = 2012.5 ft3 0.3637 ft3/ft x (2218' - 1661') x 1.35 (35% excess) = 273.5 ft3 51 ft3 +2012.5 ft3+ 273.5 ft3 = 2337 ft3 2337 ft3 / 4.45 ft3/sk = 525.2 sks Roundup to 530 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 (3018' - 2218') x 1.35 (35% excess) = 392.8 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 392.8 ft3 + 43.2 ft3 = 436 ft3 436 ft3/ 2.47 ft3/sk = 176.5 sks Roundup to 180 sks BHST = 46°F, Estimated BHCT = 63°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 (min) 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 7.0 426.6 60.9 94.2 DeepCRETE 6.0 77.7 12.9 107.1 Drop top plug 0.0 0.0 5.0 192.1 Water 5.0 20.0 4.0 116.1 Switch to rig 0.0 0.0 5.0 121.1 Mud 7.0 253.6 36.2 157.3 Slow & bump plug 3.0 9.0 3.0 160.3 MUD REMOVAL Recommended Mud Properties: 9.6 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 3 per 2 joints throughot tail slurry column. ~RI6INAL Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 4/25/2006 Prepared by: Mike Martin .Location: Anchorage, AK Phone: (907) 26311207 Mobile: (907) 748-6900 email: martin13@slb.com l '' Previous Csg. < 10 3/4", 45.0# casing at 3,018' MD < Top of Tail at 4,200' MD 7 5/8", 29.7# casing in 9 7/8" OH TD at 7,681' MD (3,619' TVD) CemCADE Preliminary Job Design 7-5/8" Intermediate Casing ~eliminary Job Design based on limited input data. For estimate purposes only ~~h~umberge~ Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C target - (3481' MD annular length). Sperry WP-05. Tail Slurry Minimum thickening time: 190 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3481' x 1.25 (25% excess) = 934.6 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 934.6 ft3 + 20.6 ft3 = 955.2 ft3 955.2 ft3/ 2.25 ft3/sk = 424.5 sks Round up to 430 sks BHST = 85°F; Estimated BHCT = 73°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) (bbl) (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 65.0 13.0 25.0 Drop bottom plug 0.0 0.0 5.0 30.0 MUDPUSH II 5.0 75.0 15.0 45.0 DeepCRETE 5.0 170.1 34.0 79.0 Drop top plug 0.0 0.0 5.0 84.0 Water 5.0 20.0 4.0 88.0 Switch to rig 0.0 0.0 5.0 93.0 Mud 6.0 320.0 53.3 : 146.3 Slow & bump plug 3.0 9.0 3.0 149.3 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: Recommend 3 per 2 joints tandem rise centralizers throughout cemented column. ORIGINAL Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular ~ To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/z' to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ~- To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" ~ To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly ~''"{~''~ Doyon 141 West Sak 3 ksi 1s-580P3KSheet1of~ ~~~~CO~'"11 ~ ~ ~~ prepared by Steve McKeever Alaska BOP Configuration ailv2oo4 ',..j af' I 20" 91.5# x 34" Insulated Conductor, K-55, set at +/. 80' 11" x 5" Vetco Gray MB 228 Wellhead 10-3/4", 45.5#, BTC ~` Shoe set @ 3018' MD, 2145' TVD, 66 deg/ Tubing String 4-1 /2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 5.1/2" X 7.818" ZXP Liner Top Packer w/ Hold Seal Assembly Downs 4.75" Seal OD Tubing, Special Drift to +/. 500' MD 3.875" DB Nipple, for Possible SSSV GLM, Camco KBG-2, 4-1/2" X 1" GLM, Camco KBG-2, 4-1 /2" X 1" CMU Sliding Sleeve, w/ 3.81" DB Nipple Casing Sealbore Receptacle, 20' Length Lateral Entry Module(LEM) D-sand Window /at 6138' MD, 3347' TVD 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint / / ~ ~;y Seal Assembly 4-112" X 78/8" Seal Bores `. 4.75" Seal OD Model 'B' HOOK Hanger 3.66" ID 1 5.112" X 7-SIB" ZXP Liner Top ~~ Packer cal Hold Downs Lateral Entry Module (LEMI Assembly ~ t~ 5-112" X 7-5/8" 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 - 3.66" 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 4-112" X 7-518" - » Model'B' HO OK Hanger e Seal Bor 3.68"ID 3.833" Ddit 3.958"ID ~t?t"1t3CC)I1~?S West Sak 7-5/8" Injector 1J-170 Tri-Lateral Completion 'D' Sand Lateral 3-112" Bent Joint 1 ~ 3.1/2" Guide Shoe I '~ I - 4-1 /2" Liner Shoe, 11.6#, L-80 BTC Set @ 12736' MD, 3470' TVD B ~I(EU6rRtE8 Baker Oil Tools Late ral Entry Module (LEM) With Diverters and Isolation Lateral Access Diverter Lateral Isolation Divener GS Running Tool Stdng Installed Installetl (3.00" Laterel Drltt) (2.50" ID Mainbore DriRj 'GS' Profile for Coil Connector fRunninglRetrieving tii ~..I (7.00'Length) I I Snap In/Snap Out reack Pressure Valve ' /POSitive LOcatingti (1,60' Length) Collet I Lateral Isolation ~~ r Flow-Thru Swivel Seals (1.25' Length) ~ Lateral Diverter ~/ Hydraulic ~ Ramp ; Disconnect ' \ IsolatioN Mainbore~r € (1.50 Length) \ Diverter Sleeve € ~~ GS Spear =t (7.50' Length) >< 1 ~~ I Lateral Isolation Seals h 6.85 k Approx. DAL• llL "Jars may he requiretl in highly deviated 16.5' Diverter Length 18.5' Sleeve Length or deep applications (6' approx length). Y Lateral Entry Module(LEM) - B-sand Window /at 6584° MD, 3434' TYD 'B' Sand Lateral 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint 3-112" Bent Joint ~ __ , ffi ~ ~,..., ° „~- 3-112" Guide Shoe ~'"~"'"°'!'°"~""-' ' '' 4-1/2" Liner Shoe, 11.6#, L•80 BTC n Set @ 12649' MD, 3525' TVD 3.552" DB Nipple 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs 5-112" X 7-516" Flex Lock Liner Hanger I Packer Assembly at Liner Hanger +/- 6684' MD Casing Sealbore Receptacle, 20' Length v .! 7-5/8" Casing, L-80, BTCM Set at ® Baker Xughes 2005. This document may not be reproduced or distdbuted, in whole or in part, in any form or @ 7661' MD, 3619' TVD (85 deg) by any means eleetronle or meehenleal, Inelutling photocopNng, recareing, or by any Infortnatlon storage and retrieval system now known or hereafter Invented, without written permission from Baker Hughes Inc. Eauipment Specifications 4-1 /2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Laterel Drill, cal diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.69" Diverter and Sleeve Length: +/- 18.5' ~ ~ 4.1/2" Casing Shoe, 11.6#, L-80 BTC Set @ 12508' MD, 3643' TVD Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral ® 4.1/2" 11.6# L-80 Slotted Liner Every Other Joint 4-1/2" Eccentric _~ / .Guide Shoe ~~ • SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO 1530 700 G ST. ANCHORAGE AK 995,~0j1 /~ /'' ~f ,Q ~/,2 PAY TO THE 5 l l I'(i ~T / (t/ / ~SF-PT ~~7 C ORDER OF • ~~~ 1145 DATE 5&1.551/441 ~ ~~ ~~ JPMorganChase ~ j valid up To 5000 ~oaars { JPMorgan Chase Bank, N:A. Columbus, OH ~ rwEnno ~ ~~ f"' ----------~~~ - --1i ` .l__ Nr -- ~:044LL55L1~:528747L9Q?927ii'LL55 I ._--~m. • • TRANSMITTAL LETTER CHECKLIST WELL NAME /~C,i2G~ ~•l ^ 17Q PTD# ~ ~O Develo ment Service Ex lorato p p ry 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 well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (SO- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.05. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 NameZhas 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 rogram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist VVELI PERMIT CHECKLIST Field & Pool KUPARUK RIVER,. WEST SAK OIL - 490150. Well Name: KUPARUK RIV U_WSAK 1J-1.70. _Program SER _ Well bore seg PTD#:2060620 Company CONOCOPHILLIPS ALASKA INC __ _ _ _ ____ _ Initial Classffype SER / PEND_ GeoArea 890 _ Unit 11160_.__ On/Off Shore On Annular Dispc -' .,.._ Administration 1 - Permit fee attached. Yes 2 Lease number appropriate Yes Surface location in ADL 025661; top productive interval and TD in ADL 025660. 3 Unique well name and number Yes 4 Well located in a defined pool Yes ~uparuk River, West Sak Oil Pool - 490150, governed by CO 4066. 5 Well located proper distance-from. drilling unit boundary Yes Well is more than 500 feet from an external property line. 6 Well located proper distance from other wells. Yes CQ 4066., Rule 3; no restrictions as to well spacing except that. no pay shall be opened in a well closer 7 Sufficient acreage available in drilling unit... Yes than 500 feet to an external-property line where ownership or landownership changes. 8 ;f deviated, is wellbore plat included Yes Well will be located 1500' from KRU boundary i 9 Operator only affected party Yes 10 Operator has appropriate. bond in force Yes 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative_approval - Yes Appr Date 13 Can permit be approved befgre 15-day wait Yes SFD 5/12/2006 ' 14 'dell located within area and strata authorized by Injection Order # (put 10# in-comments). (For Yes Area Injection Order No. 28 15 All wells within 114 mile area cf review identified (For service well only) Yes KRU 1J-1Q, 1J-168, 1 J-166,1.E-105 (toe) 16 Pre-produced injector; uuration c`pre-production'ess than. 3 months. (For service well. only) Yes David. Nugent,. GPAI, 5116106: This well will be flowed back for 30 days for clean-up. i~.CP~flP Firidiny of Consistency-has been issued for this project tJA ACMP determination. ro longer affects AOGCC approval of permit to drill. 8 __ _ __ _ _ --_ _ _- -_ Conductor stung provided es _ _ _ 20" x 34" @108'. __ - Engineering 19 Surface casing protects all known USDWs Yes 20 CMT vol adequate to circulate on conductor & surf csg Yes .Adequate excess.. 21 CMT. vol. atlequate_totie-in Jong string to surf csg No 22 CMT will cover all knownproductive horizons- - No .Slatted. 23 Casing designs adequate far G, T, B & permafrost_ Yes 24 Adequate tankage or reserve pit Yes Doyon 141. 25 If a re-drill, has a 10-403 for abandonment been approved NA New well 26 fdequate_wellboreseparationproposed- - Yes 27 ff diverter required, does it meet regulations Yes 2S Drilling fluid program schematc.& equip list adequate Yes Max MW 9 2 ppg. 4ppr Date 29 60PES do they meet regulation Yes WGA 5116(2006 30 t3UPEpress rating appropriate; test to (put psig in comments) Yes Test to 3000 psi, MSP 1239 psi. 31 Choke-manifold complies w/API_RP-53 (May 84)_ Yes 32 ' Work will occur without operation shutdown Yes . , 33 Is presence of H2S gas probable No Not an H2S area. 34 Mechanical condition of wells'evithin AOR verified (For. service well only) _ - Yes Cementing records of all AOR wells reviewed.. 35 Permit can be issued vv/o hydrogen sulfide measures Yes None expected. Rig has sensors & alarms. __ Geology 36 Rata_presented on potential overpressure zones. Yes Expected res. pressure is ~8.7 ppg EMW; will be drilled with. 8.8 ppg mud. B7 Seismic-analysis of shallow gas zones NA No shallow gas expected.. Mud program_notes use of 9 6 ppg mud if hydrates are encountered. Appr Date 38 Seabed condition survey (ifoff-shore) NA_ SFD 5/1212006 ',39 .Contact namelphone for weekly_progress reports [exploratory only] - N_A Geologic Date: Engineering Date I~ Date West Sak A sand injector. This well will the the main well bore for a tri-lateral injection well. SFD Commissioner: Commissione : ' s' r ~~~~6 a,~ s'-ib ~ 0.6 • t • Well History. File APPENDIX r1 L_J Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, iniormalion of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 18 10:02:57 2006 Reel Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library • Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-170 API NUMBER: 500292331000 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-JUL-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: W-0004406587 W-0004406587 W-0004406587 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: M. THORNTON M. THORNTON D. GLADDEN MWD RUN 6 MWD RUN 7 JOB NUMBER: W-0004406587 W-0004406587 LOGGING ENGINEER: T. GALVIN T. GALVIN OPERATOR WITNESS: D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1802 FEL: 2490 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT S(IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) 10.750 3041.0 7.625 7894.0 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 WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE' 1J-170 PB2 WELLBORE AT 11280'MD/3657'TVD. 4. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 4-7 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 1-7 REPRESENT WELL 1J-170 WITH API#: 50-029-23310-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12479'MD/3702'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.......06/07/18 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 DH STOP DEPTH GR 3004.0 12421.5 FET 3020.0 12428.5 RPX 3020.0 12428.5 RPM 3020.0 12428.5 RPD 3020.0 12428.5 RPS 3020.0 12428.5 ROP 3050.5 12479.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 3004.0 4 7900.0 5 7940.5 6 10558.0 7 11280.5 REMARKS: MERGED MAIN PASS. MERGE BASE 7900.0 7940.0 10558.0 11280.0 12479.5 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 3004 12479 7741.5 18951 3004 12479 RPD MWD OHMM 0.63 2000 34.0464 18818 3020 12428.5 RPM MWD OHMM 0.06 2000 26.541 18818 3020 12428.5 RPS MWD OHMM 1.43 288.04 22.4939 18818 3020 12428.5 RPX MWD OHMM 3.76 256.49 20.8413 18818 3020 12428.5 FET MWD HOUR 0.17 67.66 1.29589 18818 3020 12428.5 GR MWD API 20.08 126.91 69.8981 18836 3004 12421.5 ROP MWD FT/H 1.02 547.49 187.269 18858 3050.5 12479 First Reading For Entire File..........3004 Last Reading For Entire File...........12479 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3004.0 7853.5 RPD 3020.0 7845.5 RPM 3020.0 7845.5 RPX 3020.0 7845.5 RPS 3020.0 7845.5 FET 3020.0 7845.5 ROP 3050.5 7900.0 LOG HEADER DATA DATE LOGGED: 02-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 63.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7900.0 TOP LOG INTERVAL (FT) 3050.0 BOTTOM LOG INTERVAL (FT) 7900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.1 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3041.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 8.90 ~ MUD VISCOSITY (S) 63.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) 3.650 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.910 89.6 MUD FILTRATE AT MT: 3.600 70.0 MUD CAKE AT MT: 3.900 70.0 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 ......... .....Undefine d 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 N sam 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 3004 7900 5452 9793 3004 7900 RPD MWD030 OHMM 0.63 2000 21.3466 9652 3020 7845.5 RPM MWD030 OHMM 1.33 1392.15 16.2736 9652 3020 7845.5 RPS MWD030 OHMM 1.43 120.17 15.3867 9652 3020 7845.5 RPX MWD030 OHMM 3.76 115.12 13.7692 9652 3020 7845.5 FET MWD030 HOUR 0.17 52.29 0.962366 9652 3020 7845.5 GR MWD030 API 20.08 124.01 70.9391 9700 3004 7853.5 ROP MWD030 FT/H 2.52 547.49 198.517 9700 3050.5 7900 First Reading For Entire File..........3004 Last Reading For Entire File...........7900 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name..........LIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7846.0 7940.0 RPX 7846.0 7940.0 RPD 7846.0 7940.0 RPS 7846.0 7940.0 RPM 7846.0 7940.0 GR 7854.0 7940.0 ROP 7900.5 7940.0 s LOG HEADER DATA DATE LOGGED: 05-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7940.0 TOP LOG INTERVAL (FT) 7900.0 BOTTOM LOG INTERVAL (FT) 7940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 99.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 16500 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 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 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .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 7846 7940 7893 189 7846 7940 RPD MWD040 OHMM 4 2000 951.529 189 7846 7940 RPM MWD040 OHMM 0.06 2000 298.903 189 7846 7940 RPS MWD040 OHMM 10.1 174.98 31.6434 189 7846 7940 RPX MWD040 OHMM 6.72 45.49 24.5842 189 7846 7940 FET MWD040 HOUR 0.23 67.66 40.462 189 7846 7940 GR MWD040 API 34.59 73.61 53.2451 173 7854 7940 ROP MWD040 FT/H 51.06 270.1 219.321 80 7900.5 7940 First Reading For Entire File..........7846 Last Reading For Entire File...........7940 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name............~LIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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 RPX 7940.5 10508.0 RPM 7940.5 10508.0 RPS 7940.5 10508.0 RPD 7940.5 10508.0 FET 7940.5 10508.0 ROP 7940.5 10558.0 GR 7940.5 10501.0 LOG HEADER DATA DATE LOGGED: 06-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10558.0 TOP LOG INTERVAL (FT) 7940.0 BOTTOM LOG INTERVAL (FT) 10558.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.3 MAXIMUM ANGLE: 92.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 72.0 MUD PH: .0 MUD CHLORIDES (PPM): 15500 FLUID LOSS (C3) 3.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 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 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 7940.5 10558 9249.25 5236 7940.5 10558 RPD MWD050 OHMM 5.09 263.19 31.2819 5136 7940.5 10508 RPM MWD050 OHMM 4.59 2000 36.6224 5136 7940.5 10508 RPS MWD050 OHMM 4.55 288.04 35.0255 5136 7940.5 10508 RPX MWD050 OHMM 4.43 256.49 33.4605 5136 7940.5 10508 FET MWD050 HOUR 0.18 19.17 0.64405 5136 7940.5- 10508 GR MWD050 API 42.24 118.17 65.9165 5122 7940.5 10501 ROP MWD050 FT/H 1.03 432.08 199.381 5236 7940.5 10558 First Reading For Entire File..........7940.5 Last Reading For Entire File...........10558 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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 SUMMARX VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10501.5 11280.0 RPX 10508.5 11280.0 FET 10508.5 11280.0 RPS 10508.5 11280.0 RPM 10508.5 11280.0 RPD 10508.5 11280.0 ROP 10558.5 11280.0 LOG HEADER DATA DATE LOGGED: 08-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11280.0 TOP LOG INTERVAL (FT) 10558.0 BOTTOM LOG INTERVAL (FT) 11280.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.6 MAXIMUM ANGLE: 91.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 14500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 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 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 10501.5 11280 10890.8 1558 10501.5 11280 RPD MWD060 OHMM 5.12 76.96 21.0232 1544 10508.5 11280 RPM MWD060 OHMM 4.96 114.73 20.8477 1544 10508.5 11280 RPS MWD060 OHMM 4.71 57.13 17.7402 1544 10508.5 11280 RPX MWD060 OHMM 4.4 44.77 16.0414 1544 10508.5: 11280 FET MWD060 HOUR 0.27 18.46 1.71263 1544 10508.5 11280 GR MWD060 API 52.48 126.91 78.7732 1558 10501.5 11280 ROP MWD060 FT/H 2.05 257.99 148.244 1444 10558.5 11280 First Reading For Entire File..........10501.5 Last Reading For Entire File...........11280 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 0 DE PTH INCREMENT: .500 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 11280.5 12428.5 ROP 11280.5 12479.5 RPS 11280.5 12428.5 RPD 11280.5 12428.5 GR 11280.5 12421.5 FET 11280.5 12428.5 RPX 11280.5 12428.5 LO G HEADER DATA DATE LOGGED: 09-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12479.0 TOP LOG INTERVAL (FT) 11280.0 BOTTOM LOG INTERVAL (FT) 12479.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 89.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 14500 FLUID LOSS (C3) 3.4 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: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN 9 Max frames per record...:~`.......Undefined Absent value ... ............. ......-999 Depth Units .... ............. ...... Datum Specifica tion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11280.5 12479.5 11880 2399 11280.5 12479.5 RPD MWD070 OHMM 10.86 42.92 26.855 2297 11280.5 12428.5 RPM MWD070 OHMM 8.63 48.88 28.5594 2297 11280.5 12428.5 RPS MWD070 OHMM 7.08 52.83 26.7806 22.97 11280.5. 12428.5 RPX MWD070 OHMM 6.28 52.28 25.2607 2297 11280.5 12428.5 FET MWD070 HOUR 0.29 14.31 0.652116 2297 11280.5 12428.5 GR MWD070 API 51.71 117.19 69.6134 2283 11280.5 12421.5 ROP MWD070 FT/H 1.02 204.05 137.73 2399 11280.5 12479.5 First Reading For Entire File..........11280.5 Last Reading For Entire File...........12479.5 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF • End Of LIS File f Sperry-Sun DriT~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 18 14:54:10 2006 Reel Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/07/18 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 West Sak MWD/MAD LOGS WELL NAME: 1J-170 PB1 API NUMBER: 500292331070 OPERATOR: ConocoPhillips Alaska, Inc.. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-JUL-06 JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004406587 W-0004406587 LOGGING ENGINEER: P. ORTH P. ORTH OPERATOR WITNESS: M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1802 FEL: 2490 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3041.0 2ND STRING 6.750 7.625 7894.0 3RD STRING PRODUCTION STRING 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 RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 3,4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 4 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 1-4 REPRESENT WELL 1J-170 PB1 WITH API#: 50-029-23310-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9281'MD/3634'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.......06/07/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......5TSLIB.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 3004.0 RPD 3020.0 FET 3020.0 RPS 3020.0 RPM 3020.0 RPX 3020.0 ROP 3050.5 all bit runs merged. STOP DEPTH 9223.0 9230.5 9230.5 9230.5 9230.5 9230.5 9281.0 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 3 3004.0 7900.0 MWD 4 7900.0 9281.0 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 3004 9281 6142.5 12555 3004 9281 RPD MWD OHMM 0.63 2000 34.0977 12422 3020 9230.5 RPM MWD OHMM 0.06 2000 20.4025 12422 3020 9230.5 RPS MWD OHMM 1.43 174.98 15.4764 12422 3020 9230.5 RPX MWD OHMM 3.76 115.12 13.9975 12422 3020 9230.5 FET MWD HOUR 0.17 67.66 1.46893 12422 3020. 9230.5 GR MWD API 20.08 131.24 72.7532 12439 3004 9223 ROP MWD FT/H 2.52 547.49 199.668 12462 3050.5 9281 First Reading For Entire File..........3004 Last Reading For Entire File...........9281 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3004.0 7853.5 FET 3020.0 7845.5 RPX 3020.0 7845.5 RPS 3020.0 7845.5 RPM 3020.0 7845.5 RPD 3.020.0 7845.5 ROP 3050.5 7900.0 LOG HEADER DATA DATE LOGGED: 02-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7900.0 TOP LOG INTERVAL (FT) 3050.0 BOTTOM LOG INTERVAL (FT) 7900.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 63.1 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 3041.0 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: Lignosulfonate 8.90 63.0 9.3 150 5.2 3.650 70.0 2.910 89.6 3.600 70.0 3.900 70.0 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 3004 7900 5452 9793 3004 7900 RPD MWD030 OHMM 0.63 2000 21.3466 9652 3020 7845.5 RPM MWD030 OHMM 1.33 1392.15 16.2736 9652 3020 7845.5 RPS MWD030 OHMM 1.43 120.17 15.3867 9652 3020 7845.5 RPX MWD030 OHMM 3.76 115.12 13.7692 9652 3020. 7845.5 FET MWD030 HOUR 0.17 52.29 0.962366 9652 3020 7845.5 GR MWD030 API 20.08 124.01 70.9391 9700 3004 7853.5 ROP MWD030 FT/H 2.52 547.49 198.517 9700 3050.5 79.00 First Reading For Entire File..........3004 Last Reading For Entire File...........7900 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 Maximum Physical Record..65535 File Type ............... 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7846.0 9230.5 RPD 7846.0 9230.5 RPM 7846.0 9230.5 FET 7846.0 9230.5 RPS 7846.0 9230.5 GR 7854.0 9223.0 ROP 7900.5 9281.0 LOG HEADER DATA DATE LOGGED: 05-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9281.0 TOP LOG INTERVAL (FT) 7900.0 BOTTOM LOG INTERVAL (FT) 9281.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 99.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 16500 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 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 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 7846 9281 8563.5 2871 7846 9281 RPD MWD040 OHMM 4 2000 78.5289 2770 7846 9230.5 RPM MWD040 OHMM 0.06 2000 34.7897 2770 7846 9230.5 RPS MWD040 OHMM 5.22 174.98 15.789 2770 7846 9230.5 RPX MWD040 OHMM 4.98 45.49 14.793 2770 7846 9230.5 FET MWD040 HOUR 0.17 67.66 3.23406 2770 7846 9230.5 GR MWD040 API 34.59 131.24 79.1777 2739 7854 9223 ROP MWD040 FT/H 34.08 426.38 203.71 2762 7900.5 9281 First Reading For Entire File..........7846 Last Reading For Entire File...........9281 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/18 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 .....................06/07/18 Origin ...................STS Reel Name ...............OWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 18 15:14:53 2006 Reel Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/07/18 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 West Sak MWD/MAD LOGS WELL NAME: 1J-170 PB2 API NUMBER: 500292331071 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-JUL-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: W-0004406587 W-0004406587 W-0004406587 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: M. THORNTON M. THORNTON D. GLADDEN MWD RUN 6 JOB NUMBER: W-0004406587 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN 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 1802 2490 109.00 81.00 CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S(IN) 9.875 6.750 SIZE (IN) DEPTH (FT) 10.750 3041.0 7.625 7894.0 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 WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE: 1J-170 PB1 WELLBORE AT 7940'MD/3652'TVD. 4. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4-6 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 1-6 REPRESENT WELL 1J-170 PB2 WITH API#: 50-029-23310-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11916'MD/3667'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.......06/07/18 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 3004.0 11858.5 RPD 3020.0 11865.5 RPS 3020.0 11865.5 RPM 3020.0 11865.5 FET 3020.0 11865.5 RPX 3020.0 11865.5 ROP 3050.5 11916.0 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 3 3004.0 4 7900.0 5 7940.5 6 10558.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7900.0 7940.0 10558.0 11916.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep .Code Offset Channel DEPT FT 4 1 68 0 1 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 3004 11916 7460 17825 3004 11916 RPD MWD OHMM 0.63 2000 33.9805 17692 3020: 11865.5 RPM MWD OHMM 0.06 2000 25.8097 17692 3020 11865.5 RPS MWD OHMM 1.43 288.04 21.6518 17692 3020- 11865.5 RPX MWD OHMM 3.76 256.49 20.0151 17692 3020 11865.5 FET MWD HOUR 0.17 67.66 1.33097 17692 3020 11865.5 GR MWD API 20.08 126.91 70.9356 17710 3004 11858.5 ROP MWD FT/H 1.03 547.49 190.052 17732 3050.5 11916 First Reading For Entire File.....:. ....3004 Last Reading For Entire File...........11916 File Trailer • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3004.0 7853.5 RPD 3020.0 7845.5 RPM 3020.0 7845.5 RPX 3020.0 7845.5 RPS 3020.0 7845.5 FET 3020.0 7845.5 ROP 3050.5 7900.0 LOG HEADER DATA DATE LOGGED: 02-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7900.0 TOP LOG INTERVAL (FT) 3050.0 BOTTOM LOG INTERVAL (FT) 7900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.1 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESTS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3041.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) ~ 63.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.650 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.910 89.6 MUD FILTRATE AT MT: 3.600 70.0 MUD CAKE AT MT: 3.900 70.0 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 3004 7900 5452 9793 3004 7900 RPD MWD030 OHMM 0.63 2000 21.3466 9652 3020: 7845.5 RPM MWD030 OHMM 1.33 1392.15 16.2736 9652 3020 7845.5 RPS MWD030 OHMM 1.43 120.17 15.3867 9652 3020 7845.5 RPX MWD030 OHMM 3.76 115.12 13.7692 9652 3020 7845.5 FET MWD030 HOUR 0.17 52.29 0.962366 9652 3020 7845.5 GR MWD030 API 20.08 124.01 70.9391 9700 3004 7853.5 ROP MWD030 FT/H 2.52 547.49 198.517 9700 3050.5 7900 First Reading For Entire File..........3004 Last Reading For Entire File...........7900 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name..........~LIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7846.0 7940.0 FET 7846.0 7940.0 RPM 7846.0 7940.0 RPD 7846.0 7940.0 RPS 7846.0 7940.0 GR 7854.0 7940.0 ROP 7900.5 7940.0 LOG HEADER DATA DATE LOGGED: 05-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18. DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7940.0 TOP LOG INTERVAL (FT}; 7900.0 BOTTOM LOG INTERVAL (FT) 7940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 99.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 16500 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE {MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 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 .000 .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 7846 7940. 7893 189 7846 7940 RPD MWD040 OHMM 4 2000 951.529 189 7846. 7940 RPM MWD040 OHMM 0.06 2000 298.903 189 7846 7940 RPS MWD040 OHMM 10.1 1 74.98 31.6434 189 7846 7940 RPX MWD040 OHMM 6.72 45.49 24.5842 189 7846 7940 FET MWD040 HOUR 0.23 67.66 40.462 189 7846 7940 GR MWD040 API 34.59 73.61 53.2451 173 7854 7940 ROP MWD040 FT/H 51.06 270.1 219.321 80 7900.5 7940 First Reading For Entire File..........7846 Last Reading For Entire File...........7940 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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 7940.5 10508.0 FET 7940.5 10508.0 RPM 7940.5 10508.0 RPX 7940.5 10508.0 GR 7940.5 10501.0 RPD 7940.5 10508.0 ROP 7940.5 10558.0 LOG HEADER DATA DATE LOGGED: 06-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10558.0 TOP LOG INTERVAL (FT) 7940.0 BOTTOM LOG INTERVAL (FT) 10558.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.3 MAXIMUM ANGLE: 92.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 72.0 MUD PH: .0 MUD CHLORIDES (PPM): 15500 FLUID LOSS (C3) 3.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 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 7940.5 10558 9249.25 5236 7940.5 10558 RPD MWD050 OHMM 5.09 263.19 31.2819 5136 7940.5- 10508 RPM MWD050 OHMM 4.59 2000 36.6224 5136 7940.5 10508 RPS MWD050 OHMM 4.55 288.04 35.0255 5136 7940.5 10508 RPX MWD050 OHMM 4.43 256.49 33.4605 5136 7940.5 10508 FET MWDO50 HOUR 0.18 19.17 0.64405 5136 7940.5 10508 GR MWI~050 API 42.24 118.17 65.9165 5122 7940.5 10501 ROP MWD050 FT/H 1.03 432.08 199.381 5236 7940.5 10558 First Reading For Entire File..........7940.5 Last Reading For Entire File...........10558 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 • Comment Record FILE HEADER C 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 GR 10501.5 11858.5 RPM 10508.5 11865.5 RPX 10508.5 11865.5 RPS 10508.5 11865.5 RPD 10508.5 11865.5 FET 10508.5 11865.5 ROP 10558.5 11916.0 LOG HEADER DATA DATE LOGGED: 08-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11916.0 TOP LOG INTERVAL (FT) 10558.0 BOTTOM LOG INTERVAL (FT): 11916.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.6 MAXIMUM ANGLE: 91.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7894.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: •0 MUD CHLORIDES (PPM): 14500 FLUID LOSS (C3): 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 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 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 10501.5 11916 11208.8 2830 10501.5 11916 RPD MWD060 OHMM 5.12 76.96 20.1264 2715 10508.5 11865.5 RPM MWD060 OHMM 4.96 114.73 20.2456 2715 10508.5 11865.5 RPS MWD060 OHMM 4.71 57.13 17.9296 2715 10508.5 11865.5 RPX MWD060 OHMM 4.4 61.96 16.4669 2715 10508.5 11865.5 FET MWD060 HOUR 0.27 18.46 1.2168 2715 10508.5 11865.5 GR MWD060 API 39.22 126.91 81.5188 2715 10501.5 11858.5 ROP MWD060 FT/H 2.05 257.99 140.971 2716 10558.5 11916 First Reading For Entire File..........10501.5 Last Reading For Entire File...........11916 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Writing Library. Scientific Technical Services Service name .............LISTPE Date. ....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name..........~KNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File