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205-144
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-18_22130_KRU_1J-164_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22130 KRU 1J-164 50-029-23278-00 Injection Profile 18-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 205-144 T38095 10/24/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.24 10:35:38 -08'00' 1 Regg, James B (OGC) From:NSK West Sak Prod Engr <n1638@conocophillips.com> Sent:Friday, October 20, 2023 9:47 AM To:NSK Optimization Engr; Regg, James B (OGC) Cc:CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael; Krysinski, Marina L; Valentine, Doug K Subject:LPP/SSV Returned to Service on CPAI Well 1J-164 on 10/20/2023 Good AŌernoon Jim, The low‐pressure pilot (LPP) on well 1J‐164 (PTD #205‐144, #205‐145, #205‐146) was returned to service aŌer the well was SI and removed from the “Facility Defeated Safety Device Log” on 10/19/2023. The well is currently shut‐in following an IPROF due to suspected interference with an offset producer. Please let me know if you have any quesƟons. Thank you, Will Parker Senior ProducƟon Engineer – GKA (CPF1‐West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK Optimization Engr <n2046@conocophillips.com> Sent: Friday, October 13, 2023 1:38 PM To: Jim Regg <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J‐164 on 10/12/2023 Jim, The low pressure pilot (LPP) on well 1J‐164 (PTD #205‐144, #205‐145, #205‐146) was defeated last night, 10/12/2023, aŌer the well was returned to injecƟon as part of the offset producer injecƟon breakthrough diagnosƟc well work. The well is currently injecƟng in the recommended rate of ~1200 BWPD at a wellhead pressure of 100 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be noƟfied when the LPP/SSV funcƟon is returned to normal, in accordance with “AdministraƟve Approval No. CO 406B.001.” Please let me know if you have any quesƟons. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Thank you, Toon Changklungdee/Emily Zanto GKA OpƟmizaƟon Engineer – ConocoPhillips Alaska Office: (907) 659‐7411 Cell: (303) 564‐7586 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-08-11_15942_KRU_1J-164_InjectionProfile.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15942 KRU 1J-164 50-029-23278-00 Injection Profile (D Sands Lateral) 11-Aug-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: 205-144 T37931 8/15/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.15 12:37:12 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-08-04_159369_KRU_1J-164_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15939 KRU KRU 50-029-23278-00 Injection Profile 04-Aug-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: 205-144 T37914 Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.08 11:55:17 -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: Defeated LPP/Panel on CPAI Well 1J-164 on 11/30/2022 Date:Thursday, December 1, 2022 9:39:00 AM Attachments:image001.png KRU 1J-164 (PTD 2051440) 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 30, 2022 11:25 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: Defeated LPP/Panel on CPAI Well 1J-164 on 11/30/2022 Jim, The low pressure panel on well 1J-164 (PTD #205-144, #205-145, #205-146) was defeated today, 11/30/2022, after the well was returned to injection to monitor communication with an offset producer. The well is currently injecting in the recommended rate of ~1000 BWPD at a wellhead pressure of 3 PSI. The panel 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/panel function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-164 KUPARUK RIV U WSAK 1J-164 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-164 50-029-23278-00-00 205-144-0 W SPT 3424 2051440 1500 5 6 5 5 174 179 180 180 4YRTST P Adam Earl 5/7/2022 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1J-164 Inspection Date: Tubing OA Packer Depth 270 2010 1945 1940IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509092515 BBL Pumped:1.1 BBL Returned:1.1 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 3DFNHU79'LQ$2*&&GDWDEDVHLVSVL WHVWSUHVVXUHXQDIIHFWHG MEU 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:27:08 -08'00' C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-03-07_20199_KRU_1J-164_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20199 KRU 1J-164 50-029-23278-00 Injection Profile 07-Mar-22 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 FTP ______________________________ ______________________________________ 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 205-144 T36411 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.10 12:54:44 -09'00' 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. You don't often get email from toon.changklungdee@conocophillips.com. Learn why this is important From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on CPAI Well 1J-164 on 1/2/2022 Date:Monday, January 10, 2022 9:46:56 AM Ok to file in PTD 2051440 only (relates to surface equipment) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Changklungdee, Toon <Toon.Changklungdee@conocophillips.com> Sent: Friday, January 7, 2022 4:53 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>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: LPP/SSV Returned to Service on CPAI Well 1J-164 on 1/2/2022 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was returned to service and removed from the “Facility Defeated Safety Device Log” on 1/2/2022, after the well was shut in. The LPP had been defeated on 7/27/2021 after the well lost its well head injection pressure post MBE treatment. 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 WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 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-164 on 1/8/2022 Date:Monday, January 10, 2022 9:42:14 AM 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: Saturday, January 8, 2022 10:26 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>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-164 on 1/8/2022 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was defeated today, 01/08/2022, after the well was returned to injection after the injection choke had been inspected and repaired. The well is currently injecting ~1300 BWPD at a wellhead pressure of 1 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be 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 WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 1�C1 (,J-- 164 (%7_1J 2-z 5_144c, Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, July 27, 2021 9:08 AM S �e� To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska); NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI Well 1J-164 on 07/27/2021 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was defeated today, 07/27/2021, after the well was returned to injection after it tripped offline due to low wellhead pressure. This being monitored following a recent MBE treatment. The well is currently injecting —570 BWPD at a wellhead pressure of 115 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be 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, Stephanie Thomson, for Toon Changklungdee WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Regg, James B (CED) f �'(v From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, July 19, 2021 11:00 AM !�'ef ., To: Regg, James B (CED) I Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska); NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI Well 1J-164 on 7/18/2021 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" on 7/18/2021, as the injection pressure increased above the LPP setpoint from sustained injection in the pattern. The well is currently injecting 770 BWPD at 160 psi wellhead pressure. The LPP had been defeated on 7/13/2021 after the well lost its well head injection pressure post MBE treatment. 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 WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 "I 4 Prb Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, July 12, 2021 5:04 PM / To: Regg, James B (CED)` Cc: NSK West Sak Prod Engr; CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska); Thomson, Stephanie; NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI Well 1J-164 on 7/8/2021 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" on 7/8/2021, after the well was shut in for an MBE treatment. The LPP had been defeated on 7/7/2021 when the well was returned to injection to prepare for the MBE treatment. 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 WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 Kreit IJ- /4,4 Pik �Si44o Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, July 7, 2021 10:09 PM K1 7��Z�rLi To: Regg, James B (CED) Cc: NSK West Sak Prod Engr; CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska); Thomson, Stephanie; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI Well 1J-164 on 7/7/2021 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was defeated today, 07/07/2021, after the well was returned to service for an upcoming MBE treatment. The well is currently injecting —400 BWPD, with the wellhead pressure of 7 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be 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 WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 lGut 15 - )64 Regg, James B (CED) From: CP.F1 Prod Engr <n1269@conocophillips.com> Sent: Tuesday, July 13, 2021 9:08 PM 2c � 71 i 7i`U To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska); NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI Well 1J-164 on 7/13/2021 Jim, a The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was defeated today, 07/13/2021, after the well had lost its wellhead injection pressure to satisfy LPP setpoint. The well is currently injecting —650 BWPD, with the wellhead pressure of 100 PSI. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be 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 WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586Toon Changklungdee WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 Y� 2Lt IT -164 Regg, James B (CED) 705144c, From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, June 9, 2021 10:08 AM To: Regg, James B (CED) Cc: NSK West Sak Prod Engr; CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Autry, Sydney; Braun, Michael (Alaska) Subject: LPP/SSV Returned to Service on CPAI Well 11-164 on 6/8/2021 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" on 6/8/2021, as the injection pressure increased above the LPP setpoint from sustained injection in the pattern. The well is currently injecting 980 BWPD at 190 psi wellhead pressure.. The LPP had been defeated on 11/23/2020 when the well was returned to injection after an extended shut-in period. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee WestSak Production Engineer Office: (907) 659-7234 / (907) 265-1375 Cell: (303) 564-7586 NL- iCT-16�- Regg, James B (CED) Pi From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, November 23, 2020 7:13 AM Nlm To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael (Alaska); Autry, Sydney; Thomson, Stephanie Subject: Defeated LPP/SSV on CPAI Well 1J-164 on 11/23/2020 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was defeated today, 11/23/2020, after the well was returned to service after an extended shut-in period. The well is currently injecting 1,115 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 406B.001." Please let me know if you have any questions. Thank you, Stephanie Thomson / Toon Changklungdee West Sak Production Engineers Office: 907-659-7234 Cell: 832-414-2377 1 Ke&( I cT- 164- PTY� ZC'5144 0 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, June 7, 2020 2:20 PM To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F Subject: LPP/SSV Returned to Service on Well 11-164 on 6/7/2020 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 6/7/2020 after the well was shut-in. The LPP had been defeated on 5/20/2020 after the well was returned to service after an extended shut-in period. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 Regg, James B (CED) Ply Z05 -114O From: NSK West Sak Prod Engr <nl638@conocophilli s.com> Sent: Wednesday, May 20, 2020 1:10 PM 1\ IZoIZc To: Regg, James B (CED) \� 1 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI Well 11-164 on 5/20/2020 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was defe ted today, 5/20/2020, after the well was returned to service after an extended shut-in period. The well is currently injecting 977 BWPD and wellhead pressure isonvacuum. 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 Marina's Cell: (907) 399-7791 Pager: (907) 659-7000 #497 J(PA 1T— 164 F71 7,msI440 Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Monday, January 20, 2020 7:29 AM 1I2{(�ZD To: Regg, James B (CED) % Cc: CPF1 DS Lead Techs; CPF1 Ops Supv, CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI well 1J-164 on 1/20/2020 Jim, The low pressure pilot (LPP) on well IJ -164 (PTD #205-144, #205-145, #205-146) was defeated today, 1/20/2020, after the well was returned to service after an extended shut-in period. The well is currently injecting 1,257 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 Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax SERVIrl, nRnrR Delivered to: AOGCC ATTN: Natural Resources Technician II rr Alaska Oil & Gas Conservation Commision 4 333 W. 7th Ave, Suite 100 -yam Anchorage, AK 99501 2051 44 30 45 6 - • � 14Mar-19 14Mar19JW 01 WELL NAME 1R-17 1E -168L1 1C•190 1J-164 API # 50-029-22212-00 50.029-23230-60 50.029-23136-00 50-029-23278-00 # EA77.00002 E90U-00005 E90U-00006 E90U-00007 FIELD NAME KUPARUK RIVER KUPARUK RIVER I KUPARUK RIVER KUPARUK RIVER DESCRIPTIONColor WL WLIPROF WL Memory DELIVERABLE DESCRIPTION DATA r, • • r Ver2 FINAL FIELD 13 -Feb -19 1 (PROF FINAL FIELD 23 -Feb -19 1 [PROF FINAL FIELD 23 -Feb -19 IPROF1 FINAL FIELD 25 -Feb -19 1 1J-136 50-029-23331-00 E90U-00009 KUPARUK RIVER Memory IPROF FINAL FIELD 26 -Feb -19 1 2M-21 50-103.20156.00 E540-00062 KUPARUK RIVER WL Caliper FINAL FIELD 7 -Mar -19 1 6 Va Please return via Alaska PTSPri�slb 1 Lenvelope, courier or sign/scan com Tom.Osterkamnaa X Signature and email a copy S lumberger rnnnrnnh and CPAI. Date ATransmittal Receipt signature confirms that a package (box, etc.) has been received and the contents of the plckage have been verified to match the media noted above. The suecific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this p)i nt. -JW Schlumberger -Private Kea I o'- )(.* Pit zo51440 Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Tuesday, February 26, 2019 1:23 PM � J To: Regg, James B (DOA) �� zi'�1� Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara; CPF1 Prod Engr; NSK Optimization Engr Subject: LPP/SSV Returned to Service on Well 1J-164 Jim, The low pressure pilot (LPP) on well IJ -164 (PTD #205-144, #205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 2/26/2019, after wellwork was completed and tFe well was shut- in. The LPP had been defeated on 2/25/2019 after the well was returned to service to perform diagnostic wellwork. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 lot Regg, James B (DOA) Z�S14 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, December 21, 2018 9:07 AM�,,r ( 4z4li �' To: Regg, James B (DOA) r i Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara; CPF1 Prod Engr; NSK Optimization Engr; Changklungdee, Toon Subject: RE: [EXTERNAL]RE: LPP Returned to Service on CPAI well 1J-164 on 12/14/2018 Jim, I apologize for the error. Well number is 1J-164 (PTD #205-144, #205-145, #205-146) Thanks, Courtney From: Regg, James B (DOA) <jim.regg@alaska.gov> Sent: Friday, December 21, 2018 9:02 AM WANW JAN 0 2 2019 To: NSK West Sak Prod Engr <n1638@conocophillips.com> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com>; Braun, Michael (Alaska) <Michael.Bra un@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Sudan, Hari Hara <Hari.H.Sudan@conocophillips.com>; CPF1 Prod Engr <n1269@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; Changklungdee, Toon <Toon.Changklungdee@conocophillips.com> Subject: [EXTERNAL]RE: LPP Returned to Service on CPA[ well 1J-164 on 12/14/2018 PTD 2050350 is JRU 1J-154. Which well are you referencing Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, December 21, 2018 6:42 AM To: Regg, James B (DOA) <iim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com>; Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Sudan, Hari Hara <Hari.H.Sudan@conocophillips.com>; CPF1 Prod Engr <n1269@conocophilli sp com>; NSK Optimization Engr <n2046@conocophilli sp com>; Changklungdee, Toon 1 <Toon.Changklungdee@conoyiIIips.com> • Subject: LPP Returned to Service on CPAI well 1J-164 on 12/14/2018 Jim, The low pressure pilot (LPP) on well V-164 (PTD #205-035, #205-036, #205-037) was returned to service and removed from the "Facility Defeated Safety Device Log" on 12 4/2018 after the well was shut-in post well work. The LPP had been defeated on 10/30/2018 to evaluate the performance of an MBE remediation treatment, leading to low wellhead pressure while on injection. 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 • MEMORANDUM TO: Jim Regg P.I. Supervisor it FROM: Austin McLeod Petroleum Inspector 50-01 NON -CONFIDENTIAL • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 21, 2018 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. 1J-164 KUPARUK RIV U WSAK 1J-164 Src: Inspector Reviewed By: P.I. Supry `1( Comm Well Name KUPARUK RIV U WSAK IJ -164 API Well Number 50-029-23278-00-00 Inspector Name: Austin McLeod Permit Number: 205-144-0 Inspection Date: 11/18/2018 Insp Num: mitSAM181118210101 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IJ -164 'Type Inj ' TVD 3432 Tubing 2 2 1 1 PTD 2051440 Type Test SPT Test psi 1500 - IA 1110 2020 1980 1975 BBL Pumped0.9 BBL Returned: 0.6 OA 241 243 - 243 242 - Interval� aYRTST P/F "J Notes: MIT -IA Wednesday, November 21, 2018 Page 1 of I • K&t. 3- IG4- z6s (440 Reqq, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Tuesday, October 30, 2018 8:33 AM � 0 (stoo, To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara; CPF1 Prod Engr; NSK Optimization Engr Subject: Defeated LPP/SSV on CPAI well 1J-164 on 10/30/2018 Jim, The low pressure pilot (LPP) on well V-164 (PTD #205-144, #205-145, #205-146) was defeated today, 10/30/2018, after the well was returned to service yesterday to evaluate the performance of an MBE remediation treatment and wellhead pressure fell below the LPP setpoint this morning. The well is currently injecting 1,052 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 afety 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 / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. SUNNED � Office: (907) 659-7234 Pager: (907) 659-7000 #497 P -D 149,0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Q� Z-7 Sent: Thursday, September 27, 2018 5:05 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-164 on 9/27/2018 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 9/27/2018, after the wellhead pressure increased overnight. The well is currently injecting —350 BWPD at 322 psig. The LPP had been defeated on 9/26/2018 when the well was returned to service to perform wellwork. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Courtney Gallo / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Cell: (720) 318- 5762 Pager: (907) 659-7000 #497 SCAMMED NOV U a� M 2ost4go Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> q Sent: Wednesday, September 26, 2018 7:18 AM c fl�� 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; Fox, Pete B; Braun, Michael (Alaska); Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI Well 1J-164 on 9/26/2018 Jim, The low pressure pilot (LPP) on well 1J-164 (PTD #205-144, #205-145, #205-146) was defeated today, 9/26/2018, after the well was returned to service to evaluate the performance of an MBE remediation treatment. The well is currently injecting 500 BWPD at 200 psi wellhead pressure. 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. Courtney Gallo / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Cell: (720) 318- 5762 Pager: (907) 659-7000 #497 SCANNF.0 N 0 V 2 6 2018 I<eLk ( J- 164 Pb Z,6T 14A, Reqq, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Saturday, September 15, 2018 9:15 AM�—�n/ l- /%? lig,To: Regg, James B (DOA) Z 1( Cc: NSK Optimization Engr; CPF1 Ops Supv; CPF1 DS Lead Techs; CPF1&2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska) Subject: LPP/SSV on CPAI Well 1J-164 on 9/15/2018 Jim, The low pressure pilot (LPP) on well 11-164 (PTD #205-144, #205-145, #205-146) was defeated last night (9/14/2018) after the well was brought online overnight to prepare for a reservoir conformance job. The well was then shut-in this morning (9/15/2018) to pump the conformance job and the LPP was placed back in service. The LPP was recorded on the "Facility Defeated Safety Device Log" overnight while the well was online injecting 900 BWPD at an injection pressure of 65 psi. It has now been removed from the "Facility Defeated Safety Device Log". 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 NOV 2 12018 20544 29253 MMU LOGRECEIVED TRANSMITTAL MITTAL MAS' 11 2018 PwAcfm DiAgNmlic SERWcEs, Inc. AOGG�,,. To: AOGCC Natural Resources Technician 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 : 1) Injection Profile 2) Signed : Print Name: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 24 -Apr -18 1J-164 CD Np JUN U\8 2018 50-029-23278-00 Date : 6, t -�' fie PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit. docx w P -JD o Regg, James B (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, May 11, 2018 11:30 AM l To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: Recent SW MITIAs in Kuparuk and Alpine Attachments: MIT CRU CD3 -108 & CD3 -112 05-10-18.xlsx; MIT KRU 1J 102 & 164 NON WITNESSED 05-09-18.xlsx; MIT KRU 1J Pad pg 1 05-09-18.xisx; MIT KRU 1J Pad pg 2 05-09-18.xlsx. Recent SW MITIAs performed in Kuparuk and Alpine. Regards, Jan Byrne / Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 4 1WELLS TEAM SCANNED JUN 0 1201,8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim_.reaaCcDalaska.aov: AOGCC.Inspectors(Malaska.00v: phoebe. brooks(cDalaska.aov OPERATOR: ConocoPhillips Alaska Inc FIELD / UNIT / PAD: Kuparuk / KRU / 1 J Pad DATE: 05/09/18 OPERATOR REP: Duffy/Green AOGCC REP: 60 Min. 4 = Four Year Cycle chris.wallace ccD.alaska.aov Well 1J-102 Result Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4 = Four Year Cycle F = Fail PTD 2061100 Type Inj N Tubing 75 75 75 75 Type Test P Packer TVD 3524 BBL Pump 2.4 IA 0 1800 1710 1685 Interval 4 Test psi 1500 'BBL Return 1.4 OA 33 38 39 39 Result P Notes: Non witnessed Well 1J-164 Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD 2051440 Type Inj N Tubing 1340 1340 1340 1340 Type Test P Packer TVD 3424 BBL Pump 1.4 IA 140 2220 . 2165. 2155 Interval 4 Test psi 1500 - BBL Return 1.4 OA 238 241 241 241 Result P Notes: Non witnessed Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes W = Water G = Gas S = slurry I = Industrial Wastewater N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 1J 102 164 NON WITNESSED 05-09-18 INTERVAL Codes Result Codes TYPE TEST Codes P = Pressure Test I = Initial Test P = Pass O = Other (describe in Notes) 4 = Four Year Cycle F = Fail V = Required by Variance I = Inconclusive O = Other (describe in notes) MIT KRU 1J 102 164 NON WITNESSED 05-09-18 37— 164 P%1c) 005-i4*0 Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophiIIips.co > Sent: Wednesday, April 25, 2018 3:57 PM `I` C' A 1 2,6ll$ To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK West Sak Prod Engr; NSK Optimization Engr Subject: LPP/SSV Returned to Service on CPAI Well 1J-164 on 4/25/2018 Jim, The low pressure pilot (LPP) on well J-164 (PTD #205-144 205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" to ay, /2018, after the well was shut-in following the completion of wellwork. The LPP had been defeated on 4/20/2018 when the well was returned to service to perform wellwork. This notification is in accordance with "Administrative Approval No. CO 4068.001." 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 Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax APR IS 2018 '• f Delivered to: SCANNED MAY 0 J,2010 AOGCC «• ATTN: Natural Resources Technician II } Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 20 5144 29 177 WELL NAME 1L-23 API # 50-029-22167-00 SERVICE ORDER # DTBP-00058 FIELD NAME KUPARUK RIVER SERVICE DESCRIPTION WL DELIVERABLE DESCRIPTION Perf DATA TYPE FINAL FIELD Color DATELOGGED Prints 29 -Mar -18 CD' 1 2A-10 50-103-20056-00 DTBP-00059 KUPARUK RIVER WL Caliper FINAL FIELD 30 -Mar -18 1 U-154 50-029-23254-00 DQMD-00039 KUPARUK RIVER Memory IPROF FINAL FIELD 3 -Apr -18 1 31-1-04 50-103-20076-00 DTBP-00065 KUPARUK RIVER WL WFL FINAL FIELD 7 -Apr -18 1 U-164 50-029-23278-00 DQMD-00040 KUPARUK RIVER Memory IPROF FINAL FIELD 7 -Apr -18 1 3S-21 50-103-20452-00 DTBP-00068 KUPARUK RIVER WL (PROF FINAL FIELD 10 -Apr -18 1 30-20 50-029-22750-00 DSOS-00111 KUPARUK RIVER WL Plug FINAL FIELD 11 -Apr -18 1 30-20 50-029-22750-00 DSOS-00112 KUPARUK RIVER WL Caliper FINAL FIELD 12 -Apr -18 1 1H-116 50-029-23594-00 DSOS-00113 KUPARUK RIVER WL WFL FINAL FIELD 13 -Apr -18 1 1H-119 50-029-23591-00 DSOS-00114 KUPARUK RIVER WL WFL FINAL FIELD 14 -Apr -18 1 1H-114 50-029-23584-00 DSOS-00115 KUPARUK RIVER WL WFL FINAL FIELD 15 -Apr -18 1 11 Transmittal Receipt q A Transmittal Receipt signature confirms that a package (box, In envelope, etc.) has been received and the contents of the / 1 J%&, X 0' �5 package have been verified to match the media noted above. The Print Name Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy to Schlumberger and CPAI. point. Alaska PTSPrintCenter@slb.com Tom.Osterkamp@conocophillips.com JSLB Auditor- �; 1 1 (J— 14 265- t440 Reqq, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, April 8, 2018 6:29 AM 7ef, 4-11(,t To: NSK West Sak Prod Engr; 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-164 on 4/7/2018 Jim, The low pressure pilot (LPP) on wellflJ-164 (PTD #205-144 #205-145, #205-146) was returned to service and removed from the "Facility Defeated Safety Device Log" last nig t, 4/7/2018, after the well was shut-in following the completion of wellwork. The LPP had been defeated on 4/5/2018 when the well was returned to service to perform wellwork. This notification is in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any questions. Evan Reilly for Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 \. Prtm 2asia+0 Reg% James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, April 5, 2018 3:26 PM 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-164 on 4/5/2018 Jim,----- i� � The low pressure pilot (LPP) on well J-164 PTD #205-144, 205-145, #205-146) was defeated today, 4/5/2018, after the well was returned to service to perfo m wellwork. The well is currently injecting 1125 BWPD at 132 psi wellhead pressure. 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. Sydney Autry for Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main RECEIVED NOV 17 2017 AOC (907)273-4760 fax Delivered to: 67MakanaK Bender �• \ Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W 7'= • Regg, James B (DOA) Pt6 &,�514Aey From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, July 25, 2016 9:17 AM To: Regg, James B (DOA) �( I Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr Specialist; CPF1 Prod Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on CPAI well 1J-164 Jim, The low pressure pilot (LPP) on well IJ -1 (PTD #20E,15 205-145, 205-146) was returned to service today, 7/25/16. The well has stabilized at a wellhead injection pressure of 530 psig and rate at 1100 BWPD, and has been removed from the "Facility Defeated Safety PvicP Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCAINMIE® JA4l 2 � 0 Regg, James B (DOA) le K C(,k 1 T-164- Rr--6 zos144.0 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, July 19, 2016 2:16 PM 2&q -7(tq J1(ra To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI well 1J-164 Jim, The low pressure pilot (LPP) on well 1J-164 TD #205-144, 205-145, 205-146) was defeated today, 7/19/16, after the wellhead injection pressure fell below 00 psig. The well is currently injecting 1100 BWPD at 460 psig wellhead pressure. The LPP and surface safety valve (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Lo." The AOGCC will be notified when the well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCANNED JAH 112017, 11 � 205 k 41� z40JAV0 WELL LOG TRANSMITTAL # DATA LOGGED %% /;$0/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper (MFC): 1J-164 Run Date: 10/11/2015 November 19, 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-164 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23278-00 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 Office: 907-275-2605 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed: G�✓���1'uv _����y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well Plug Perforations r' Perforate r Other r7o WINJ to WAG Alter Casing r Pull Tubing Stimulate - Frac" Waiver r Time Extension"" Change Approved Program rOperat. Shutdown (' Stimulate - Other r Re-enter Suspended Well " 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory Stratigraphic ("" Service 205-144 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL025661; ADL025650 1J-164 10. Field/Pool(s): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11400 feet Plugs (measured) NonR E j E I V EIA true vertical 3745 feet Junk (measured) None NDY, 12 2014 Effective Depth measured 11398 feet Packer (measured) 4185 feet (true vertical) 3424 AOGCC true vertical 3745 Casing Length Size MD TVD Burst Collapse CONDUCTOR INSULATED 78 20 108 108 SURFACE 2303 10.75 2333 2203 D -SAND WINDOW 10 7 4258 3442 D LINER LEM 188 6.61 4375 3474 B -SAND WINDOW 10 7 4604 3513 INTERMEDIATE 5331 7.625 5358 3660 A -SAND LINER 6697 6.59 11400 3745 Perforation depth: Measured depth: 55886 -5710;5802 -6049;6384 -6846;7524 -7774;8144-8545;9087-9427;9705-9766;10286-10592;11179-11365 True Vertical Depth: 3664 -3667;3687 -3697;3698 -3687;3672 -3674;3698 -3697;3686-3695;3706-3684;3677-3680;3692-3709;3731-3743 Tubing (size, grade, MD, and TVD) 4.5, L-80, 4222 MD, 3423 TVD Packers & SSSV (type, MD, and TVD) SEAL ASSY - BAKER SBE SEAL ASSEMBLY @ 4185 MD and 3424 TVD SSSV = NIPPLE @ 475' MD / 475' TVD 12. Stimulation or cement squeeze summary: ryry ifi Intervals treated (measured): CA JAN Treatment descriptions including volumes used and final pressure:`^' 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 1229 1431 663 Subsequent to operation 3021 — 132 1661 14. Attachments 15. Well Class after work: Exploratory r Development r Service r7 Stratigraphic Copies of Logs and Surveys run 16. Well Status after work: Oil r Gas WDSPL Daily Report of Well Operations xx GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact Bob Christensen/Darrell Humphrey Email n1139(d)conocophillips.com Printed Name Robikt D. Christensen Title NSK Production Engineering Specialist Signature J Phone: 659-7535 Date Q Z/ Z Form 10-404 Revised 10/2012 VL_ r 212 Z f 14-p�Op , — i _e. - Su Pi�al , 1 tZ 1k.. Date Event Summary 05/16/14 1J-164 DESCRIPTION OF WORK COMPLETED SUMMARY State witnessed (Lou Grimaldi) MIT -IA (PASSED) to 1990 psi. Initial T/1/0 = 606/1140/387. IA FL @ SF. Pressured IA to 1990 psi w/.5 bbls diesel. Starting T/I/O = 605/1990/387. 15 min T/1/0 = 606/1960/387. (-30). 30 min T/I/O = 606/1950/387. (-10) Bled IA to 1235 psi. Final T/I/O = 605/1235/386. 11/07/141 Commenced WAG EOR Injection Cono4hillipS KUP NN t s .1J.4 6/13201312.31 31 PM +��. ScN'�malic AOEuaI CONDUCTOR 1-1. ed, Perforations & Slots ---3Q1➢8_ ------ ------- NIPPLE, 475 Top (ND) TODI.KB1 B l.KBl I --I SEAL ASSY, 4,185 D -SAND WINDOW, 4.248-4,258 D LINER LEM, 4,1874,375 B - SAND WINDOW, 4.5944,604 B LINER LEM, Q TO (1J-164). 11,400 BSAND LINER, 4,587-11,452 D -SAND it 4,246-11,503 Date lan... /122005 32.0 S /122005 32.0 S /12/2005 32.0 S Annotation 64), B -SAND (lJ- 31.01 IJ -164 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C20 5 - I L+ 1+ Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 1 1 _4 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation` YES BY: Maria Date: d' J 13 1 a 8 Stage 9 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: NO /s/ 91 P NO /s/ QualityChecked Illilllllllltllllll 10/6/2005 Well History File Cover Page.doc III IIIIII II III II III III II'lII II II III III Organizing (done) Two-sided ❑ Rescan Needed ;,CAN Color items: DIGITAL DATA Diskettes, No. OVERSIZED (Scannable) Maps: ❑ ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non -Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: F-1 Other: BY: Maria Date: �— / Q� I t /s/ Yi Project Proofing IIIIIIIIIIIIII IIIII BY:Maria Date: �, D �j /s/ Scanning Preparation x 30 = 0 + J13 = TOTAL PAGES 113 _ rr-1� (Count does not include cover sheet) BY: Maria Date: 'q, (,moi (� /s/ Production Scanning Stage 1 Page Count from Scanned File: 1 1 _4 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation` YES BY: Maria Date: d' J 13 1 a 8 Stage 9 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: NO /s/ 91 P NO /s/ QualityChecked Illilllllllltllllll 10/6/2005 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, July 09, 2014 P.I. Supervisor & -7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IJ -164 FROM: Lou Grimaldi KUPARUK RIV U WSAK 1J-164 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J661 NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK IJ -164 API Well Number 50-029-23278-00-00 Inspector Name: Lou Grimaldi Permit Number: 205-144-0 Inspection Date: 5/16/2014 Insp Num: mitLG140516073928 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j IJ -164 Type Inj W- TVD 3432 IA 1140 1990 1960 - I 1950 - -- -- ---- -- ---- PTD� zos144o TYPe Test SPT Set psi 1500 OA 387 387 387 387 Interval j4YRTST jP/F P Tubing 606 . 1 605 606 606 ' Notes: .5 bbl's diesel pumped, .3 bbl's returned. All supporting documentation provided by DHD supervisor Ron Wilson. 1 SCANNED OCT 31 2014 --L- -A Wednesday, July 09, 2014 Page 1 of 1 CHOKE FTT OAP 1200 FTP IAP TWO Plot - 1J-164 Pr-'�> Z05-4461 200 1000 -� .......................................................................................+ 150 V Q, a� CL 100 c 600 ........... ......................... .............................. o T m 50 200 -{- ...................................................................................... 0 -1-1 i 1-1 4 }-1 1 -1 1 I 1 1- 1 1 1 F F 1--1---F- 1 4 0 16 -Feb -14 01 -Mar -14 14 -Mar -14 27 -Mar -14 09 -Apr -14 22 -Apr -14 05 -May -14 Date Page 1 of 2 0 • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n 1 638@conocophillips.com] Sent: Thursday, September 22, 20114:34 PM To: NSK West Sak Prod Engr; CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist Subject: LPP/SSV Returned to Service on 1 J-164 West Sak injector Tom and Jim, The low pressure pilots (LPP) on the well listed below has been returned to service on 9/22/2011 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure pressure and injection rate are also listed below. This pilot had been defeated on 9/16/2011 in accordance with "Administrative Approval No. CO 406B.001." The injection pressures has increased on the following wells so as to remain above 500 psi and the LPP/SSV function has been returned to normal. Well Permit to Drill #s Rate (BW� PD) 1 -164 _,_(205-1 05-145, 205-146) 1725 Wellhead Injection Pressure (PSI) Injection 558 In addition to the LPP being returned to service on 1J-164, 1 have summarized the current defeated LLP situation at 1J below. The wells in red still have LI -Ps defeated, and the others wells have been returned to service with their returned to service date at the end. An email has been sent for all wells that have had their LLP returned to service. Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 From: CPF1 Prod Engr Sent: Friday, September 16, 20116:44 PM To: 'tom.maunder@alaska.gov'; 'jim.regg@alaska.gov' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist, Gauer, Jenn L Subject: RLPP/SSV defeated on multiple 13 West Sak injectors: 16 -Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) Returned to normal 9/23/2011 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Friday, September 16, 2011 6:44 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP/SSV defeated on multiple 1J West Sak injectors: 16 -Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Rate (BWPD) 1J-105 (207-027,207-028,207-029) 1 J-118 (206-176,206-177,206-178) 1 J-127 (206-047,206-048, 206-049) 1J-154 (205-036,205-037) 1J-160 (207-015,207-016,207-017) 1 J- (205-144.V05-145, 205-146) 1 J-180 (206-150,206-151) 1J-184 (206-044,206-045) Wellhead Injection Pressure (PSI) Injection 345 639 327 1020 337 934 369 623 352 568 479 1082 537 478 502 646 The AOGCC will be notified when the injection pressures have increased so as to remain 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. David Lagerlef/Dan Bearden CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 9/19/2011 Page 1 of 1 Maunder, Thomas E (DOA) From: Gauer, Jenn L [Jennifer.L.Gauer@conocophillips.com] Sent: Wednesday, December 08, 2010 10:49 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; Gauer, Jenn L; Pierson, Chris R; CPF1 Prod Engr Subject: LPP/SSV Returned to service on 1J-164 - 12-8-2010 Tom / Jim, The low pressure pilot (LPP) on tri -lateral injectort1540442W444, 205-145 L1, 205-146 L2) was returned to service on 12/08/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 530 psig; injection rate is 1691 bwpd. This pilot had been defeated on 11/10/2010 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. West Sak Production Engineer ConocoPhillips Alaska, Inc. Work - 907.265.6782 Mobile - 303.248.6641 From: Pierson, Chris R Sent: Wednesday, November 10, 2010 8:30 AM To: CPF1 Prod Engr; "Maunder, Thomas E'; "Regg, James B' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt Subject: LPP/SSV defeated on 13-164 - 11-10-2010 Tom / Jim, The low pressure pilot (LPP) on tri -lateral injector 1J-164 (205-144, 205-145 L1, 205-146 L2) was defeated on 11/10/2010 when the well was returned to injection service after being shut since 10/14/10. Current wellhead pressure (as of 08:25 11/10/10) is 312 psi at an injection rate of 460 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. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 12/9/2010 n U Maunder, Thomas E (DOA) Page 1 of 1 From: Pierson, Chris R [Chris. R. Pierson@conocophillips.com] Sent: Wednesday, November 10, 2010 8:30 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt Subject: LPP/SSV defeated on 1J-164 - 11-10-2010 Tom / Jim, The low pressure pilot (LPP) on tri -lateral injector 1J-164 (205-144, 205-145 L1, 205-146 L2) was defeated on 11/10/2010 when the well was returned to injection service after being shut since 10/14/10. Current wellhead pressure (as of 08:25 11/10/10) is 312 psi at an injection rate of 460 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. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 NGV 1 0 2010 Cell: 240-5056 11/10/2010 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Monday, May 24, 2010 � P.I. Supeergvisor h&l� �f i r c SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-164 FROM: Bob Noble KUPARUK RIV U WSAK 1J-164 Petroleum Inspector Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Suprys�— Comm Well Name: KUPARUK RIV U WSAK 13-164 Insp Num: mitRCN100516145118 Rel Insp Num: API Well Number: 50-029-23278-00-00 Permit Number: 205-144-0 Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-164 ' Type Inj. W -'I TVD 3432 '' IA 140 1700.,/ 1690 1690 P.T.D 2051440 jTypeTest SPT Test psi 1700 OA 731 731 732 732 Interval4YRTST PAF P ' Tubing 580 578 576 1 576 Notes:I I�vo��; Monday, May 24, 2010 Page I of I • 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. i 64 DATE: FIELD / UNIT / PAD: Kuparuk / KRU / 1J�/ � DATE: 05/14/10 OPERATOR REP: Colee / Phillips - AES r l'V"� AOGCC REP: Bob Noble 5 r� MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.xls I/ V I/ M Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 I Type Inj. W TVD 3,566' Tubing 657 656 655 654 Interval 4 P.T.D. 2061100 I Type test P Test psi 1500 Casing 990 1,700L 1,680 1,680 -P/Fj P Notes: OA 165 2051 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 1 Type test P Test psi 1500 Casing 1,098 1,8001 1,780 1,780 P/F P Notes: OA 155 156F 156 156 Well 1J-118 Type Inj. W I TVD 1 3,599' Tubingj 657 658 658 658 Interval 4 P.T.D. 2061760 1 Typetestj P I Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OAJ 175 192 177 175 Well 1J-122 Type Inj. I G I TVD 1 3,684' Tubing 1,751 1,751 1,751 Zgl,7501In ervall 4 P.T.D. 2070700 I Type test I P I Test psi 1 1500 Casing 809 1,690 1,640 1,620 P/F P Notes: OA 141 2141 174156 Well11-127 Type Inj. W TVD 1 3,482' Tubing 620 620 622 622 Interval 4 P.T.D. 2060470 1 Type test P Test psi 1500 Casing 1,020 1,7001 1,680 1,680 P/F P Notes: OA 206 273T 260 253 Well1J-136 Type Inj. N I TVD 3,503' Tubing 600 600 600 600 Interval 4 P.T.D. 2061540 1 Typetestj P I Test psi 1 1500 Casing 276 1,700 1,670 1,660 P/F P Notes: OA 173 1831 182 180 Well 1J-154 Type Inj. W I TVD 1 3,437' Tubingj 624 624 624 624 Interval 4 P.T.D. 2050350 1 Typetestj P I Test psi 1 1500 Casing 1 1,098 1,850 1,840 1,840 P/F P Notes: OAJ 527 527 527 527 Well1J-156 Type Inj. W I TVD 1 3,410' Tubingj 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casingl 1,147 1,900 1,890 1,890 P/F P Notes: OAJ 206 206 206 205 Well I 1J-160 Type Inj. I W I TVD 1 3,212' Tubing 626 6262P626 iQ 625 Interval 4 P.T.D. 2070150 I Type test I P I Test psi 1 1500 Casing 925 1,6801 1,650 1,640 P/F P Notes: OA 332 333 333 334 MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.xls I/ V I/ M TYPE INJ Codes TYPE TEST Codes D = Drilling Waste Packer Depth G = Gas Pretest Initial 15 Min. 30 Min. A = Temperature Anomaly Survey W = Water Well 1J-164 I Type Inj. W TVD 3,424' Tubing 5801 5781 5761 5761 Interval 4 P.T.D. 12051440 1 Type test I P Test psi 1500 Casing 1401 1,7001 1,6901 1,690 P/F P Notes: OA 7311 7311 7321 732 Well 1J-170 Type Inj. I G I TVD 3,392' Tubing 1,863 1,865 —1,866 1,866 Interval 4 P.T.D. 2060620 I Type testl P I Test psi 1500 Casing 440 2,6001'2,560 2,550 P/F P Notes: OA 155 3041 243 217 Well 1J-176 I Type Inj. I W I TVD 1 3,159' Tubing 665 Interval 4 P.T.D. 2070990 I Type test I P I Test psi 1 1500 Casing 1,268 P/F Notes: Test inconclusive OA Pumped 10 and pressured up 100 psi. Need to top off and retest. 170 Well 1J-180 I Type Inj. W TVD 3,290' Tubing 5841 584 585 587 Interval 4 P.T.D. 2061500 I Type test I P I Test psi 1500 Casing 1,0501 1,690 1,680 1,680 P/F P Notes: OA 1451 226 225 224 Well 1J-184 I Type Inj. I W I TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 I Type test I P I Test psi 1 1500 Casing 9251 1,700 1,680 1,680 P/F P Notes: OA 1651 220 178 172 TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.xls M V INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) Page 1 of 1 Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Thursday, April 15, 2010 2:49 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R Subject: LPP/SSV Returned to Service on 1J-164 - 04-15-2010 Tom / Jim, The low pressure pilot (LPP) on tri -lateral injector 1J-164 PTD 205-144 05-145, 205-146) was returned to service on 04/15/2010 after the wellhead injection pressure stabilize above the setting of the low pressure pilot. Current wellhead pressure is 537 psig; injection rate is 1,202 bwpd. This pilot had been defeated on 03/28/10 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 x wt 1A Iv, -Jt 1 From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Sunday, March 28, 2010 9:49 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R Subject: RE: LPP/SSV defeated on 1J-164, 28 -Mar -10 Tom / Jim,. The low pressure pilot (LPP) on 1J-164 (PTD 205-144, 205-145, 205-146) was defeated on 03/28/2010 when the well was returned to injection service for a logging job. The well had been shut in since March 3, 2010. Current wellhead injection pressure (as of 2100 3/28) is 170 psi at 1470 BWPD injection. 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. Kenneth Lloyd Kenneth Lloyd Martin/David Lloyd Lagerlef Prod. Eng. Regional Advisor/Staff Engineer CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 Voice Page: 659-7000 pager # 765 n U WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Shut-in Bottom Hole Pressure: 1J-164 Run Date: 7/26/2009 October 23, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J-164 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23278-00 t . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.ba - h to ern Date: lies � t 4 nhlrp(c; J'bt`) 1 Signed: () A 0 0 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Sunday, October 11, 2009 11:28 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV no longer defeated on 1J-164 - 11 -OCTOBER -09 Tom / Jim, The low pressure pilot (LPP) on 1J-164 (PTD 205-144, 205-145, 205-146) was returned to service on 10/11/2009 when the wellhead pressure became stable above 500 psi. Please let me know if you have any questions. David Lloyd Lagerlef/Kenneth Lloyd Martin CPR Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 10/12/2009 LPP/SSV defeated on IJ -164,13 -Aug -2009 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [nl638@conocophillips.com] Sent: Thursday, August 13, 2009 2:52 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Pierson, Chris R; CPF1 Prod Engr Subject: LPP/SSV defeated on 1J-164, 13 -Aug -2009 Tom / Jim, The low pressure pilot (LPP) on 1J-164PTD 205-144 205-145, 205-146) was defeated on 13 -Aug -2009 when the well was returned to injection service. The well had been shut in since 3 -Jul -2009. Current wellhead injection pressure is 134 psi; injection rate is 1077 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. Eric Hollar West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-265-6525 Cell 907-748-0181 8/13/2009 s r�r,t ij L LPP/SSV no longer defeated on 1J-164 - 4 -JULY -09 Page I of I Is 0 Maunder, Thomas E (DOA) From: CPF1 Prod Engr[nl269@conocophillips.com] Sent: Saturday, July 04, 2009 5:09 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV no longer defeated on 1 J-164 - 4 -JULY -09 Tom / Jim, The low pressure pilot (LPP) on IJ -164 (PM 205-144, 205-145, 205-146) was returned to service on 7/4/2009 when the well was shut in for f6ture well work. Please let me know if you have any questions. David Lloyd Lagerief/Kenneth Lloyd Martin CPF1 Production Engineers nl269@conocophillips.com 659-7493 pager 659-7000 765 a�Av i� JU! L � �r 2 EDSO 7/5/2009 0 Scbkmbepgep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # r y/ Log Description JUN 1 9 2069 Alaska Oii & Cas Cons. Commission NO. 5284 Anchorage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/17/09 113-19 ANHY-00091 PRODUCTION PROFILE 1 q L— < 05/27/09 1 1 3K-16 ANHY-00094 GLS 05/29/09 1 1 3G-10 1304C-00058 INJECTION PROFILE 05/31/09 1 1 1J-160 B2WY-00006 MEMORY INJECTION PROFILE Q4 05/31/09 1 1 1J-164 B2WY-00009 MEMORY INJECTION PROFILE 06/01/09 1 1 U-1601-2 AXBD-00028 MEMORY INJECTION PROFILEU 06/07/09 1 1 1 A -04A B04C-00040 RSTI C 05/05/09 1 1 3M -03A AZJZ-00011 CH EDIT SFRT 01/11/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 0 • LPP/SSV defeated on 1J-164 - 14 -JUNE -09 Page 1 of 1 40 0 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Sunday, June 14, 2009 6:53 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV defeated on 1J-164 - 14 -JUNE -09 Tom / Jim, The low pressure pilot (LPP) on f 'II ;{M2W'M+i,; 205-145, 205-146) was defeated on 6/14/2009 when the well was returned to injection service after being shut in for 14 days. Current wellhead pressure is 303 psi; injection rate is 1150 bwpd. We expect to have the LPPs returned to service in approximately one week. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers nl269@conocophillips.com 659-7493 pager 659-7000 765 6/15/2009 11 MEMORANDUM TO: Jim Regg P.I. Supervisor C� FROM: Bob Noble Petroleum Inspector L State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IJ -164 KUPARUKRIV U WSAK 1J-164 Src: Inspector NON -CONFIDENTIAL Reviewed By: P.I. Supry 1x Comm Well Name: KUPARUK RN U WSAK 1J-164 Insp Num: mitRCN090526120150 Rel Insp Num: API Well Number: 50-029-23278-00-00 Permit Number: 205-144-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-164 Type Inj. W TVD 3424 IA 1400 2010 2000 2000 P.T.D 2051440 TypeTest SPT Test psi 2010 OA 902 903 903 903 Interval 4YRTST P/+ P Tubing 529 524 524 524 Notes: Wednesday, May 27, 2009 Page 1 of 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 'SCAMED SEP 1 2 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 0 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6',2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • r� L ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 U-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 U-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 1 6" NA 6" 1 NA 1 1.28 9/6/2008 U-184 1 206-044 1 8" NA 8" 1 NA 1 1.28 9/6/2008 1J-122, IJ -164, 1J-116 LPP's hack in service Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, March 26, 2008 11:24 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Rodgers, James T Subject: 1J-122, 1J-164, 1J-176 LPP's back in service Tom/Jim, Page 1 of 1 We got behind with reporting the following low pressure pilots (LPP) defeat status changes. The LPP on the following wells were returned to service on the indicated dates after injection pressures increased to above 500 psi. 1J-122 (PTD 207-070, 207-071, 207-072). Returned to service 3/12/08. Current injection rate/pressure: 1317 bwpd @ 550 psi. A1J-16 (PTD 205-144 205-145, 205-146). Returned to service 2/28108. Current injection rate/pressure: 865 1J-176 (PTD 207-099, 207-100). Returned to service. Current injection rate/pressure: 1731 bwpd @ 647 psi. This note is in reference to "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Hai Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: nl638@ConocoPhillips.com 3/26/2008 LPP/SSV returned to service o* 164 Page 1 of 2 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [nl638@conocophillips.com] Sent: Saturday, March 01, 2008 4:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; Allsup - Drake, Sharon K; CPF1 DS Lead Techs; NSK Problem Well Supv Subject: LPP/SSV returned to service on 1 J-164 Tom / Jim, The wellhead injection pressure on 1J-164 has come up above 500 psi. The low pressure pilot (LPP) on 1J-164 was returned to normal service on 2/28/2008. Permit to drill numbers are 205-144, 205-145, 205-146. Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 k . c MAR Zt�N From: CPF1 Prod Engr Sent: Friday, December 28, 2007 3:34 PM To: 'Maunder, Thomas E (tom.maunder@aiaska.gov)'; 'Regg, lames B Oim.regg@alaska.gov)' Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Rodgers, James T Subject: LPP/SSV defeated on 11-164 Tom / Jim, Water Injection well 1 J-164 has been injecting steadily since April 2006. There has been a recent decline in the injecting wellhead pressure and the low pressure pilot (LPP) for this well has been defeated to allow continued WI support. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The permit to drill numbers for the 1 J-164 are as follows: 205-144, 205-145, 205-146. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Denise Titus (907)-659-7493 For: 3/21/2008 Message 0 0 Maunder, Thomas E (DOA) From: NSK Problem Well Supv[0617@conocophillips.com] Sent; Wednesday, February 08, 2006 6:38 PM To: Thomas Maunder Subject: RE: Verbal approval to convert Wsak IJ -164 from PreProduction to WINJ Tom, — \ %--\ L,'\ Sounds reasonable to me. I see that Jerry sent the MIT data to you. Please let me know if you need anymore information MJ Loveland ConocoPhillips Problem Well Supervisor NELr J bil "3 ;') 2 0 U 659-7224 Page 1 of 3 -----Original Message----- CS�ro�\o ZCo��\ 'C��C From: essage----- From: Thomas Maunder [mailto.,tom_Maunder@admin.state.ak.us] Sent: Wednesday, February 08, 2006 11:47 AM Ab To: NSK Problem Well Supv Cc: NSK Prod Engr Tech; Jim Regg Subject: Re: Verbal approval to convert Wsak 13-164 from PreProduction to WINJ Marie, We do need some record of a MIT having been done. Normally when the drilling rig runs the completion, the tubing. and IA pressure tests are noted as part of the narrative. I have checked the well record and there is no mention of having set the packer and conducted any pressure tests at that time. I am remembering that some MIT form has been being submitted on injection wells to document the pressure tests when completed. I J-164 may be different due to the "pre -produced" operations and the need to reset valves/close sleeves. Since a MIT was done with that work, even if "informal", I would think that CPAI requires documentation so it doesn't seem that submitting a report of that accomplishment would be to difficult. This information would satisfy the requirement of 20 AAC 25.412 (c). Am I missing something here? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 2/8/2006 11:21 AM: Tom, For new injectors, MITs completed during post rig or conversion weilwork have not typically been submitted to AOGCC. The MiTs are typically done by the SL crew that replaced the SOV with a DV or by the CTU crew that close a sliding sleeve. This is the case for 1J -164s 12/2005 MIT. The AOGCC MIT form was 7/6/2009 Message 0 0 not filled out in the field and there are no plans to fill one out for submission. For 1 J-164, a witnessed MITIA will be performed after the well is 1301 and the data submitted to AOGCC as usual. Please let me know if this is acceptable. Thanks, Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: essage----- From: Thomas Maunder [ma ilto:tom—maunder@admin.state.ak.us] Sent: Wednesday, February 08, 2006 9:22 AM To: NSK Prod Engr Tech Cc: NSK West Sak Prod Engr; AOGCC North Slope Office Subject: Re: Verbal approval to convert Wsak 13-164 from PreProduction to WIN] Page 2 of 3 Bob, I have completed my assessment of the cement isolation for 1J-164, -L I and -L2 and determined that the well construction meets the requirements for conversion to injection. By copy of this email, you have verbal approval to proceed as planned. I will look forward to seeing the three 403s sometime next week. I do not show having received a copy of the MIT you refer to in your message. Please send that in to Bob Fleckenstein/Jim Regg as usual. Once the well is warmed up, you should contact the Inspector for a witnessed MIT. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 2/8/2006 7:52 AM: Bob, I have to do a little paperwork in here. I will get back with you later this morning. Tom Maunder NSK Prod Engr Tech wrote, On 2/8/2006 7:42 AM: Tom, We have completed the Preproduction phase to recover the oil based drilling muds in Wsak IJ-164/L1/L2 (PTCWs: 206-144, 205-145, 205- 146). Well 1J-164 was originally permitted as a WNJ well, The 10.407 was completed with the well as a Oil producer for the preproduction period. An MITIA was performed on 12/21/05; MITIA 3000 psi, 30 minutes, Passed. We intend to turn the well to WINJ on or about 02/14/06. 7/6/2009 Message n U 0 I am currently working up the 10-403 conversion application but due to the tinning I am requesting a verbal approval to proceed with the conversion. Bob Buchholz / Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) 7/6/2009 Page 3 of 3 0 Maunder, Thomas E DOA From: Thomas Maunder [tom maunder@admin.state.ak.us] Sent: Wednesday, February 08, 2006 3:32 PM To: Dethlefs, Jerry C Cc: Jim Regg Subject: Re: CPA MIT for well 1 J-164 U Jerry, Thanks much. This completes the "packet". Cement log for this well looked really good. Tom Dethlefs, Jerry C wrote, On 2/8/2006 3:15 PM: > Tom: Attached is the MIT data you were looking for on West Sak well > 1J-164. A witnessed test will be scheduled when the well is put in > service. Call if you have any questions. <<MIT KRU 1J-164 > 12-21-05.xls>> > Jerry Dethlefs > Problem Well Supervisor > ConocoPhillips Alaska > 907-659-7043 1 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test 0 Email to: Winton_ Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska KRU 1J-164 12/21/05 Starck/CPAI Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 I Type Inj. I N TVD 3,423 Tubi 170 170 170 170 Interval O P.T.D. 2051440 T pe test P Test psi 1500 Casingi 2251 2,9951 2,9WJ 2,9421 PIF I I P Notes: Post rig by Coiled Tubing Unit OAJ 2001 2001 2001 200 Well Type Inj. I TVD I I Tubing I I I I Interval P.T.D. Type test Test psi I Casing I I I I I P/F Notes: LOA Weill I Type Inj. TVD I I Tubing I I I I Interval P.T.D.1 I Type test I J. Test psif I Casing P/F Notes: I OA Weill Type I.i.1 I TVD I Tubing I I Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: I OA Welli I Type Inj. I I TVD I I Tubing I I Interval P.T.D. Type test Test psi Casing P;- Notes: I OA TYPE [NJ Codes TYPE TEST Codes D = Drilling Waist M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Waistewater R = internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test MIT Report Form BFL 9/1/05 MfT KRU 1J-16412-21-05.x1s INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T=Test during Workover O = Other (describe in notes) Message 0 Maunder, Thomas E (DOA) From: NSK Prod Engr Tech [nl 139@conocophillips.com] E Page 1 of 2 Sent: Tuesday, December 20, 2005 10:24 AM To: Thomas Maunder; Allsup -Drake, Sharon K Cc: NSK Problem Well Supv; Spencer, Jeffrey A; Rodgers, James T; Steve McMains; CPF1 Prod Engr CPF2 Prod Engrs; CPF3 Prod Engrs; NSK West Sak Prod Engr Subject: RE: 1 J-154 and IJ -164 et al Tom, 1 have attempted to contact Sharon but have been unsuccessful. It is possible that the 10-407's are already in the mail as injectors. I have notified Hai Hunt of verbal approval to begin producing the following wells: U-154 [205-035] 500292325400 U-1541-1 [205-036] 500292325460 �J-1541-2 [205-037] 500292325461 J�ifi., tr 3 2 0 0 1J-164 f205-1441 500292327800 1J -164L1 [205-145] 500292327860 U-1541-2 [205-146] 500292327861 In the event of your receipt of the 10-407's completed as injectors please contact Bob Buchholz to generate 10- 403's for these wells. SHARON, Please adjust you work process as described in this thread. Bob Buchholz / Bob Christensen, Greater Kuparuk Area Production Engineering Technician A-0 Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924)�� -----Original Message----- ( C) From: Thomas Maunder[mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, December 20, 2005 10:02 AM To: NSK Prod Engr Tech Cc: NSK Problem Well Supv; Spencer, Jeffrey A Rodgers, James T; Steve McMains Subject: Re: 13-154 and 13-164 et al Bob, Based on our most recent discussion, I wanted to confirm what we discussed on 1J-154 [205-035] (and laterals) and 1J-164 [205-144] (and laterals). Both of these wells are ultimately planned to be injection wells and were permitted as such. As a follow-on to our earlier call, you have informed me that it is intended to "preproduce" both of these wells for up to 90 days. I have checked our records and the completion reports (Form 407) have not been filed. When the completion reports are filed, the status should be 1 -OIL. When it is determined to convert the wells to injectors, the process outlined in your original message should be followed. Thanks for checking on this matter. Again, please be sure that Sharon in Drilling is aware of this. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 12/20/2005 9:14 AM: 7/6/2009�� Message 0 0 Page 2 of 2 Bob, This is as we discussed. There really isn't any approval to employ this process so far as I can see.. This process will work, based on what I understand is CPAI's intent to preproduce all injectors. That intent makes the initial completion 1 -OIL as you note. Please be sure that Drilling Management and Sharon Allsup -Drake in drilling are aware of this process. Sharon files the 407's. Call or message with any questions. Tom Maunder, PE AOGCC NSK Prod Engr Tech wrote, On 12/20/2005 9:05 AM: Tom, Per our discussion yesterday pertaining to the sundry process workflow for Wsak Pre Produced Injectors, I am requesting the following approval to reduce confusion and paperwork for these cases. 1) The permit to drill 10-401 is obtained as an Injector (SVC) well. 2) The well completion 10407 will designate the well as a Development well (1- OIL). 3) A subsequent Sundry Application 10-403 conversion from 1 -OIL to 1-VVINJ will be obtained prior to commencement of Injection. 4) A subsequent Sundry Report 10-404 (Injection) will be fled within 30 days post conversion. Basically I would like to substitute the 10-407 for a 10-403. This will stop any confusion and will reduce the reporting by 1 document. Please let us know if we can proceed with this change in the process as soon as possible. Bob Buchholz / Bob Christensen Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) 7/6/2009 • i r�`a is ii" ` J i y p to <tA MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_lnsettsMcrofilm—Markerdoc DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051440 Well Name/No. KUPARUK RIV U WSAK 1J-164 Operator CONOCOPHILLIPS ALASKA INC MD 11400 TVD 3745 Completion Date 12/5/2005 Completion Status 1 -OIL Current Status 1 WINJ REQUIRED INFORMATION Mud Log No DATA INFORMATION Log Media Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Received Log/ Electr Data Digital Dataset TvnA Med/Frmt Number Name ,ZD D Lis 13765 Induction/Resistivity GR EWR4 ABI ROP ACAL Cement Evaluation Directional Survey iwAsc 13765 LIS Verification Mg Injection Profile Blu 1 C Lis 15024 Induction/Resistivity Lig Injection Profile Ultra Sonic Imager Cement Injection Profile g Injection Profile Well Cores/Samples Information: Interval Name Start Stop Samples No API No. 50-029-23278-00-00 Directional Survey (Yes , -- (data taken from Logs Portion of Master Well Data Maint Log Scale Log Media Run No Interval Start Stop OH / CH Received Comments 2297 11342 Open 4/6/2006 GR EWR4 ABI ROP ACAL PWD GeoPilot 5 Blu 1 3000 5280 Case 11/21/2005 Ultra Sonic Imager Cement Bond Log 12 November 2005 0 0 Open 1/17/2006 DEFINITIVE SURVEY 2297 11342 Open 4/6/2006 GR EWR4 ABI ROP ACAL PWD GeoPilot Blu 1 4160 4680 Case 7/25/2006 Injection Profile w/ Welltec Tractor 19 -Jun -2006 2297 11400 Open 4/17/2007 LIS Veri, GR, FET, CALA, ROP w/Graphics CGM, EMF, PDF 5 Blu 4100 4614 Case 4/20/2007 Injection profile Welltrac Conveyance 17 -Apr -2007 5 Blu 4090 4643 Case 4/20/2007 Injection profile Welltrac Conveyance 16 -Apr -2007 5 Blu 1 4100 4700 Case 1/22/2008 Injection profile mactrac Conveyance 4 -Jan -2008 Sample Set Sent Received Number Comments 0 DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051440 Well Name/No. KUPARUK RIV U WSAK 1J-164 Operator CONOCOPHILLIPS ALASKA INC MD 11400 TVD 3745 Completion Date 12/5/2005 Completion Status 1-0I1- Current Status 1WINJ ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y -i -N -- Analysis Received? Comments: Compliance Reviewed By: Daily History Received? )1 4 Formation Tops �N Date: API No. 50-029-23278-00-00 UIC Y 0 West Sak Injector 1J-164: Nation of Defeated Low Pressure PiIOC Page 1 of 1 Maunder, Thomas E (DOA) From: Hollar, Eric Andrew [Eric.A.Hollar@conocophillips.com] Sent: Wednesday, January 23, 2008 9:53 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; Allsup - Drake, Sharon K; CPF1 DS Lead Techs; NSK Problem Well Supv Subject: West Sak Injector 1J-164: Notification of Defeated Low Pressure Pilot (LPP) Tom / Jim, This email is to notify the AOGCC that the West Sak Injector 1.1-164(PTDNo.s 2V54441105 -145 L1 / 205-146 1-2) Low Pressure Pilot (LPP) is defeated as of 1/22/2008. This s in accordance wr' t� drdministrative Approval No. CO 40613.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log." The 1J-164 was shut in on 1/5/2007, and restarted 1/22/2008. Current injection rate is 1800 BWPD, injection pressure at the wellhead is 50 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 1/23/2008 0 0 schlumbepp Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ! � < Log Description NO. 4550 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Date BL Kuparuk Color CD 01/11/08 1J-164 11964565 INJECTION PROFILE 01104/08 1 3Q-22 11970623 PRODUCTION PROFILE — / 01/04/08 1 3R-21 11964567 LDL 9 - 01/06/08 1 3J-12 11970620 INJECTION PROFILE Z 1'6S - Q 01/01108 1 31-1-1013 11964562 PATCH EVALUATION/LDL U= — 01/01/08 1 1F-01AL1 11994591 FLOWING BHP SURVEY 005--C)73 12/20107 1 2N-342 11964561 OILPHASE SAMPLER - 12/31107 1 2L-330 11970618 SCMT 12/30107 1 2A-20 10194199 RST - 10/30/07 1 1 2X-19 11850441 RST ' - 07/09/07 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. LPP/SSV defeated on 1J-164 0 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Friday, December 28, 2007 3:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Rodgers, James T Subject: LPP/SSV defeated on 1J-164 Tom / Jim, Page 1 of 1 Water Injection well 1J-164 has been injecting steadily since April 2006. There has been a recent decline in the injecting wellhead pressure and the low pressure pilot (LPP) for this well has been defeated to allow continued WI support. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The permit to drill numbers for the 1 J-164 are as follows: 205-144, 205-145, 205-146, 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, Denise Titus (907)-659-7493 For: Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x791 2/7/2008 Ll 1 / VV ♦ KV1V{.L{.VK Vll lYd 1 i � � av aa... � av a v .� « � �� — --p- v � v Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-180 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr[mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 11-102, 1J-127, 13-164, IJ -180 Tom / Jim, The LPP/SSV's on all of the West Sak DS1 E and DS1J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I wasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as well so i included both. WELL ID Permit to Drill No. 1 E-112 204-091 (MAINBORE), 204-092 (L1), 204-093 (L2) 1J-102 206-110 (MAINBORE), 206-111 (L1), 206-112 (L2) 1J-105 207-027 (MAINBORE), 207-028 (L1), 207-029 (L2) 1J-127 206-047 (MAINBORE), 206-048 (L1), 206-049 (L2) 1J-160 207-015 (MAINBORE), 207-016 (L1), 207-017 (L2) ----� 1J-164 205-144 (MAINBORE), 205-145 (L1), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Hunt / Pete Nezaticky / Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 LrrlaaV UCICQLCU V11 1G-11Gy*1VG, 1J-iG/� 1J-1V`F, 1J -IOU 0 rage, 1 U1 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, August 15, 2007 2:01 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180-- 50 Tom / Jim, The Low Pressure Pilots (LPP) for West Sak Water Injectors 1 E-112, 1J-1 02, 1 J-127, U-164, and 1J-180 were defeated because of low wellhead injection pressure. These wells were shut in for a few days starting August 9 (CPF1 ESD/Coalescer shut down), allowing bottom hole pressure to fall off. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." We expect the bottom hole pressures to build back up in a few days. 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 or concerns. Regards, Hai Hunt Hai Hunt / Eric Hollar / Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: nl638@ConocoPhillips.com 8/16/2007 Schlumhergr n�R u 700 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 04/20/07 1A-10 11638846 INJECTION PROFILE 04/05/07 1 2L-3.13 11628996 LDL 04/08/07 1 1D-137 11628997 INJECTION PROFILE 04/09/07 1 2N -31.1A N/A USIT 04/06/07 1 2N -337B 11638852 SCMT 04/11/07 1 1J-184 11638853 SBHP 04/12/07 1 IH -10 11638844 GLS 03/20/07 1 2W-03 11649957 MEM LDUPPROF 04/10/07 1 1E-112 11638856 INJECTION PROFILE 04/14/07 1 1J-156 11638857 INJECTION PROFILE 04/15/07 1 1J-127 11638859 INJECTION PROFILE 04/17/07 1 1J-105 11628994 USIT 04/06/07 1 IJ -164- 11638858 INJECTION PROFILE 04116/07 1 1J-164 11638860 INJECTION PROFILE 04/17/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 13 0 Is 0 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-164, Ll, L2 & L2 PB I, 0 April 16, 2007 AK -MW -4025932 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-164, 1J-164 L1, 1J-164 L2 & 1J-164 L2 PBI: LIS & Digital Log Images: 50-029-23278-00, 60, 61, 70. , APP R 1 2007 U.TC los -Ivy ' iSoay U7c '� IS-006- 0 50aS 0 15-6Q 1 CD Rom LPP Defeated On West Sak Injectors at DS1J 0 0 Subject: LPP Defeated On West Sak Injectors at DSIJ From: NSK West Sak Prod Engr <n1638@conocophi11ips.com> Date: Sun, 14 Jan 2007 10:08:32 -0900 To: "Tom Maunder:" <tom_maunder@admin.state.ak.us>, "Jim Regg:" <jim_regg@admin.state.ak.us> CC: CPF1 DS Lead Techs <nl 140@conocophillips.com>, CPFI Prod Supt <n 1132@conocophillips.com> Tom / Jim, --�. ass -tL-�L-k 1) The Low Pressure Pilot (LPP) for 1J-164 was defeated on 1/8/07 in accordance with "Administrative Approval No. CO 4066.001." 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 will 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 a3(0-Q),-�\ 1J-154 1406 BWPD, 612 PSI o0 '-> 1J-156 3613 BWPD, 586 PSI aOCo --(3�0 1J-170 2737 BWPD, 540 PSI XU0 0(0 Regards, Hai Hai Hunt / Pete Nezaticky 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 RE: LPP Defeated On West Sak Injectors at DSIJ 0 171 Tom / Jim, j --'t a05 �LALA The Low Pressure Pilot for 1 J-164 was placed back in service after the WHP came up above 500 psi. 1J-154 still has its low pressure pilot defeated. Regards, Hai Hai Hunt / Peter Nezaticky West Sak Production Engineer ConocoPhillips Alaska, Inc. email: n1638Cconocophillips.com phone: (907) 659-7061 pager: (907) 659-7000 pager# 836 -----Original Message ----- From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Tuesday, August 22, 2006 7:36 AM To: Tom Maunder:'; 'Jim Regg:' Cc: CPF1 DS Lead Techs; NSK West Sak Prod Engr Subject: LPP Defeated On West Sak Injectors 13 - Tom / Jim, This email is to notify the AOGCC that 1J-154 and 1J-164 West Sak injectors, LPP (Low Pressure Pilot) have been defeated on 08/21/06 in accordance with "Administrative Approval No. CO 406B.001 ". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". Both wells required a non-adjustable choke insert on the water injection line to limit and control water injection at lower rates. Following are the current well conditions: 1J-154: Converted from pre -production to injection 04/10/06. Injecting 530 bwpd at 480 psi. 1J-164: Converted from pre -production to injection 04/02/06. Injecting 1850 bwpd at 480 psi. 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 Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 8/31/2006 10:08 AM LPP Defeated On West Sak Injectors 1J - Tom / Jim, This email is to notify the AOGCC that 1J-154 and 1J-164 West Sak injectors, LPP (Low Pressure Pilot) have been defeated on 08/21/06 in accordance with "Administrative Approval No. CO 40613.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". Both wells required a non-adjustable choke insert on the water injection line to limit and control water injection at lower rates. Following are the current well conditions: 1J-154: Converted from pre -production to injection 04/10/06. Injecting 530 bwpd at 480 psi. 1J-164: Converted from pre -production to injection 04/02/06. Injecting 1850 bwpd at 480 psi. �-, 3 o5 - t %-kL 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 Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 8/31/2006 10:13 AM Sckhmbergerl Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 3887 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/24/06 1E-102 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE 05/20/06 1 1 E-1051-1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 31YI-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D -125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 IF -15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1D-101 NIA INJECTION PROFILE 06/27/06 1 2Z-13 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 1 11320986 1PRODUCTION LOG 06/28/06 1 Pi 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 21 1 - Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • MEMORANDUM API Well Number Permit Number State of Alaska Alaskaod Gas Conservation Commission Inspector Name: Lou Grimaldi Inspection Date 4/25/2006 Packer DATE: Monday, May 22, 2006 _ TO: Jim ReggaG P.I. Supervisor (� - SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 3424 IA 740 1J-164 FROM: Lou Grimaldi P.T. 2051440 KUPARUK RIV U WSAK 1J-164 Petroleum Inspector TCSt psi 1500 OA NON -CONFIDENTIAL Src: Inspector ] � 44 tJL�v Well Name: KUPARUK RIV U WSAK IJ -164 Insp Num mitLG060425133713 Rel Insp Num MITOP000001105 API Well Number Permit Number 50-029-23278-00-00 205-144-0 Inspector Name: Lou Grimaldi Inspection Date 4/25/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11-164 'Type Inj. I W I TVD 1 3424 IA 740 1625 1590 �� 1585 � P.T. 2051440 TypeTest I SPT TCSt psi 1500 OA 455 455 455 455 Interval Initial Test P/F Pass Tubing 130 130 130 130 Notes Initial MIT after being brought on-line. Monday, May 22, 2006 Page 1 of I RECEIVED STATE OF ALASKA •��� ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Cis Lis _,' REPORT OF SUNDRY WELL OPERATIONS fJa1i3f9 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑u Prod to WINJ " 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 ❑ Strati ra hic g p ❑ Exploratory ❑ Service ✓ ❑ 205-144 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-164 B. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field f West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11400' feet true vertical 3745' feet Plugs (measured) Effective Depth measured 11398 feet Junk (measured) true vertical 3745 feet 4-1/2" Casing Length Size - MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2223' 10-3/4" 2332' 2203' INTERMEDIATE 5249' 7-5/8" 5358' 3443' PROD. CASING 1' 7" 4249' 3512' WINDOW B -SAN 1' 7" 4596' Perforation depth: Measured depth: None true vertical depth: None Tubing (size, grade, and measured depth) 4-1/2", L-80, 4221' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 475' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbi Gas-Mcf Water -Bbl G asing Pressure Tubing Pressure Prior to well operation 2053 2678 850 360 Subsequent to operation 2115 1000 346 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service E 16. Well Status after proposed work: Daily Report of Well Operations _X Oil❑ Gas F1 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 N/A if C.O. Exempt: 3o�--aS Contact Robert D. Christensen Printed Name Title Production Engineering Technician Signature Phone 907-659-7535 Date f R Form 10-404 Revised 04/2004 BF APR 7 7��� 7 "o ��1 �� od Subvi� Ori10 ly 0 IJ -164 0 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/2/2006 Commenced Water Injection Service 1J-164 West Sak LPP Defeated Notification 00 406B.001 0 Subject: 1J-164 West Sak LPP Defeated Notification Per CO 406B.001 From: NSK West Sak Prod Engr <nl638@conocophillips.com> Date: Sun, 02 Apr 2006 16:31:39 -0800 To: Tarn Maunder <tom maunder ,admin.state.ak us>, Jim Regg <jim re99@admin.state.ak.us> CC: NSK Problem Well Supv <n I 617@conocophillips.com>, GPFI DS Lead Techs <nl 140@conocoph llips.com>, NSK West Sak Prod Engr <nl638@a conocophillips.com> Tom / Jim, _-;�- c7O 3— l LA t_` This email is to notify the AOGCC that 1J-164, a West Sak pre -produced injector, has been placed on injection April 2, 2006 and is currently injecting 1000 bwpd on a vacuum. The LPP (Low Pressure Pilot) has been defeated and 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". 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 Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 6/12/2007 1:23 PM WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs H-164, 1 LDWG formatted Disc with verification listing. API# : 50-029-23278-00 March 24, 2006 AK -MW -4025932 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, Alaska 99518 Date:Ae� ulz Signed: li� 1-j • ALASKA OIL A" GAS CONSERVATION COl► USSION Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River, 1J-164 Sundry Number: 306-049 Dear Mr. Christensen: • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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. C11- --1- DATED this /Oday of February, 2006 STATE OF ALASKA CR ?.—IV -0�� EC E I VE D ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAEEB 1 0 2006 20 AA(9'i 2Rn 1. Type of Request: Abandon ❑ Suspend ❑ Operation Shutdown ❑ Perforate Affla Oils• p"stion Other ❑ Alter casing ElRepairwell ❑ Plug Perforations ❑ StimulateTime [:] Anc�ora�0 ❑ xten on Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑✓ Stratigraphic ❑ Exploratory ❑ Service ❑ 205-144 ✓t 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ✓. 50-029-23278-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-164 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11400' 3745' 11398 3745 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 2223' 10-3/4" 2332' 2203 INTERMEDIATE 5249' 7-5/8" 5358' 3443 WINDOW D -SAND 1' 7" 4249' 3512 WINDOW B -SAND 1. 7" 4596' 3656 A sand Slotted Liner 5966' 4-1/2" 11365' 3743 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None— None 4-1/2" L-80 4221' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV-- NIP SSSV= 475' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 21 BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 02/14/06 Oil ❑ WAG❑ Gas ❑ GINJ ❑ Plugged ❑ Abandoned ❑ WINJ ❑ WDSPLCommission /O6 16. Verbal Approval:ORTorin Representative: Maunder 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert D. Christensen Printed Name ob ChrisrdM nen Title: Production Engineering Technician Signature Phone 659-7535 Date Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: S 8FL FEB 1 3 2000 SubsequelbS—� APPROVED BY !� 1 Approved COMMISSIONER THE COMMISSION / ..• Date: (�J Form 10-403 Revised 07/2005 ✓ ` , M Submit in Duplicate 0 IJ -164 0 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Multi -lateral Well 1J-164. This well was pre -produced for a 39 day period in order to recover Solids Free Oil based drilling fluids prior to putting the well on injection. Well 1 J-164 will provide pressure support for the West Sak A sands. The 10-3/4" Surface casing (2332' and / 2203' tvd) was cemented with 480 sx AS Lite followed by 145 sx DeepCrete. The 7-5/8" Intermediate casing (5358' and / 3656' tvd) was cemented with 230 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer D - Lateral Hook Hanger LEM w/isolation Seal Bore located @ 4187' and / 3424' tvd. This well also contains a Lower A sand 5-1/2" x 7-5/8" ZXP Liner Top Packer w / HRD located @ 4703' and / 3533' tvd. The top of West Sak D sand was found at 4219'md / 3434' tvd. The top of West Sak B sand was found at 4578'md / 3509' tvd. The top of West Sak A sand was found at 4770'md / 3548' tvd. - - .' • • KRU IJ -164 ConocoPhillips Alaska, lno Re: Verbal approval to convert Wsak IJ -164 from PreProduction to... 0 is Bob, I have completed my assessment of the cement isolation for 1 J-164, -L1 and -L2 and determined that the well construction meets the requirements for conversion to injection. By copy of this email, you have verbal approval to proceed as planned. I will look forward to seeing the three 403s sometime next week. I do not show having received a copy of the MIT you refer to in your message. Please send that in to Bob Fleckenstein/Jim Regg as usual. Once the well is warmed up, you should contact the Inspector for a witnessed MIT. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 2/8/2006 7:52 AM Bob, I have to do a little paperwork in here. I will get back with you later this morning. Tom Maunder NSK Prod Engr Tech wrote, On 2/8/2006 7:42 AM: Tom, We have completed the PreProduction phase to recover the oil based drilling muds in Wsak 1J-164/1-1/1-2 (PTD#'s: 205-144, 205-145, 205-146) . Well 1J-164 was originally permitted as a WINJ well. The 10-407 was completed with the well as a Oil producer for the preproduction period. An MITIA was performed on 12/21/05; MITIA 3000 psi, 30 minutes, Passed. We intend to turn the well to WINJ on or about 02/14/06. I am currently working up the 10-403 conversion application but due to the timing I am requesting a verbal approval to proceed with the conversion. Bob Buchholz / Bob Christensen ConocoPhillips Alaska: Inc. Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) 1 of 1 2/10/2006 9:32 AM Re: Verbal approval to convert Wsak IJ -164 from PreProduction to... 0 0 Bob, I have completed my assessment of the cement isolation for 1J-164, -Ll and -L2 and determined that the well construction meets the requirements for conversion to injection. By copy of this email, you have verbal approval to proceed as planned. I will look forward to seeing the three 403s sometime next week. I do not show having received a copy of the MIT you refer to in your message. Please send that in to Bob Fleckenstein/Jim Regg as usual. Once the well is warmed up, you should contact the Inspector for a witnessed MIT. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 2/8/2006 7:52 AM: Bob, I have to do a little paperwork in here. I will get back with you later this morning. Tom Maunder NSK Prod Engr Tech wrote, On 2/8/2006 7:42 AM: Tom, We have completed the PreProduction phase to recover the oil based drilling muds in Wsak 1J-164/1-1/1-2 (PTD#'s: 205-144, 205-145, 205-146) . Well 1J-164 was originally permitted as a WINJ well. The 10-407 was completed with the well as a Oil producer for the preproduction period. An MITIA was performed on 12/21/05; MITIA 3000 psi, 30 minutes, Passed. We intend to turn the well to WINJ on or about 02/14/06. 1 am currently working up the 10-403 conversion application but due to the timing I am requesting a verbal approval to proceed with the conversion. Bob Buchholz / Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) I of 1 2/8/2006 9:23 AM HEC'- NICAL INTEGRITY REPORT � �J� uD -- _ ��:_T_ : � �,-- �5 OPER & FIELD 77C, ICT -1-7 —0 5 WELL NUM3 tR HELL DAT:_ TD Casing:_ 'i`'l�` Shoe MD Shoe -moo' Packer HD ole S�ze and INTEGRITY _ ?-A-RT #1 :'-anulus gess Test: =P Co=ents . 71L TVD ; - B TD : ?1D I jTD �(o�CzTVD ; liJ : Im �.�N-,TV�}i TVD ; Tl:? t.0 . , J 'E CHS N 1 C.1 -.I. INTEGRITY _ p� -r 12 Cement Volumes:- Amt.Liner Set Perfs 15 Min 0 min Csa 03C DV 1� A i C7 CmZ: -jol to cover per=s z 6/ :_eorec�cal TCC f Cement Bond Log es (Yes or No) s In AO CC File r rJ � CBL Evaluation, cone above perfs ``' +� �23 . •cis - c� �,�5. - cj c �e�csc Production Log: Type Evaluation CONCLUS?ONS: ?art i 1 ?art .12: 'fir ConoC-OAPhillips January 5, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Well Completion Reports for 1J-164, 1J-1641-1 and 1J-1641-2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1 J-164, 1 J-1641-1, 1 J-1641-2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RTlskad RECEIVEU STATE OF ALASKA 1 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT A-Nt SMC°"x'Wm 1a. Well Status: Oil ❑✓ Gas Lj Plugged Abandoned Suspended WAG ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WDSPL ❑ No. of Completions _ Other _ 1b. WeII Class: Development ❑✓ Exploratory ❑ Service ❑ Stratigraphic Test 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: December 5, 2005 12. Permit to Drill Number: 205-144/ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 1, 2005 13. API Number: 50-029-23278-00 4a. Location of Well (Governmental Section): Surface: 1919' FSL, 2517' FEL, Sec. 35, T11N, R10E, UM At Top Productive Horizon: 473' FNL, 2203' FWL, Sec. 35, T11 N, R1 OE, UM Total Depth: 266' FSL, 2189 FWL, Sec. 23, T11 N, R1 OE, UM 7. Date TD Reached: November 10, 2005 14. Well Name and Number: 1J-164 8. KB Elevation (ft): 28* RKB 15. Field/Pool(s): Kuparuk River Field West Salk Oil Pool 9. Plug Back Depth (MD + TVD): 11398' MD 13745' TVD 4b. Location of Well (State Base Plane Coordinates): Surface: x-558693 y- 5945730 Zone -4 TPI: x-558108 y- 5948613 Zone -4 Total Depth: x- 558041 - 5954632 Zone -4 10. Total Depth (MD + TVD): 11400' MD / 3745' TVD 16. Property Designation: , ADL 25661, 25650 11. Depth where SSSV set: nipple @ 475' 17. Land Use Permit: ALK 471, 468 18. Directional Survey: Yes ❑✓ No 19. Water Depth, if Offshore:20. N/A feet MSL Thickness of Permafrost: 3077' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM SETTING DEPTH TVD HOLE CEMENTING RECORD TOP BOTTOM SIZE AMOUNT PULLED 20" x 34" 62.58# H-40 28' 108' 28' 108' 42" 325 sx AS 10.75" 45.5# L-80 28' 2333' 28' 2202' 13.5" 480 sx AS Lite, 145 sx DeepCrete 7-5/8" 29.7# L-80 28' 5358' 28' 3656' 9-718" 230 sx DeepCrete 4.5" 12.6# L-80 4703' 11400' 3533' 3745' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slotted liner from 5399'-11365' MD 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET 4.5" 4222' 4703' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 31, 2005 Method of Operation (Flowing, gas lift, etc.) Production shared with 1J-1641_1 and 1J-1641_2 Date of Test 1/4/2006 Hours Tested 15.5 hours Production for Test Period --> OIL -BBL 694 GAS -MCF 844 WATER -BBL 0 CHOKE SIZE 176bean GAS -OIL RATIO 1292 Flow Tubing press. 693 psi Casing Pressure not available Calculated 24 -Hour Rate -> OIL -BBL 1025 GAS -MCF 1324 WATER -BBL 1 OIL GRAVITY - API (torr) 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". C tN NONE FlImm 0rWWFL JAN 18 2006 1 Lggzs Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Ah dIIIIIIIIIN 28.29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-164 West Sak A2 5365' 3657' Base West Sak A2 11400' 3745' N/A 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: Mike Greener @ 263-4820 Printed Nam Rand Thoma Title: Greater Kuoaruk Area Drilling Team Leader _ , (5 (V 6 Signature ne 2Date Prepared by Sharon Allsup -Drake 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 Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: 10/31/2005 00:00 - 02:30 2.50 WAITON EQIP MOVE Change top drive saver sub to 4-1/2" IF. 02:30 - 03:00 0.50 WAITON EQIP MOVE Service top drive & Drawworks. 03:00 - 03:30 0.50 WAITON EQIP MOVE Change Iron Rough Neck, Elvators, Dog collar Etc. over to 5" Handling tools. 03:30 - 07:00 3.50 MOVE DMOB MOVE Rig down rig for move. 07:00 - 12:00 5.00 MOVE MOVE MOVE Move rig f/ 1J-154 to 1J-164 12:00 - 12:30 0.50 MOVE MOVE MOVE Spot Sub over 1J-164 12:30 - 15:30 3.00 MOVE MOVE MOVE Lay Mats and Spot Pits, Pumps, Motors, Boilers, Lay herculite and Spot Rock Washer and Pipe sheds. 15:30 - 18:00 2.50 MOVE RURD RIGUP Hook up all service lines, Steam, Air & Water lines, Work on rig acceptance check list. 18:00 - 20:30 2.50 DRILL PULD RIGUP Accept rig @ 18:00 hrs 10/31/05, Load Pipe shed with 45 jts. 5" drill pipe, 29 its. HWDP & jars, Strap same, Begin mixing spud mud. 20:30 - 22:30 2.00 WELCTL NUND RIGUP Nipple up 20 1/4" Diverter, All lines, Bell nipple, Diverter line, Apply steam to warm up diverter, Continue to mix spud mud. 22:30 - 00:00 1.50 DRILL PULD RIGUP Pick up 21 its. 5" drill pipe and stand back in derrick, Continue to mix spud mud. 11/1/2005 00:00 - 02:15 2.25 DRILL PULD RIGUP Finish picking up total of 15 stands 5" drill pipe, 10 stands HWDP (Including Jars). 02:15 - 02:45 0.50 DRILL PULD RIGUP Bring lifters, Stab, UBHO sub, Crossover subs, to floor thru beaver slide. 02:45 - 03:45 1.00 DRILL PULD RIGUP Pick up 3 -Non Mag DC's and stand back in derrick, Lay down mouse hole. 03:45 - 04:00 0.25 WELCTL BOPE RIGUP Function test Diverter system, Test waived by AOGCC Jeff Jones. 04:00 - 05:00 1.00 DRILL PULD SURFAC Make up Bit, Motor, 1 stand HWDP, Flood conductor and check for leaks, Pressure test mud lines to 3000 psi -OK, Tag ice plug @ 80', Clean out to 108'. 05:00 - 06:30 1.50 DRILL DRLG SURFAC Spud well @ 05:00 hrs 11/1/05, Drill f/ 108' to 212' MD, 212' TVD (104'), ADT 1.00 hrs, 420 gpm @ 525 psi, 55 RPM. 06:30 - 07:00 0.50 DRILL TRIP SURFAC POOH f/ 212' to 30'. 07:00 - 08:00 1.00 DRILL PULD SURFAC Finish picking up BHA #1, Pick up Stab, X10 subs, MWD, Orient Motor w/ MWD. 08:00 - 08:30 0.50 DRILL RIRD SURFAC PJSM, Rig up Sperry -Sun GYRO & Wire unit. 08:30 - 09:00 0.50 DRILL TRIP SURFAC RIH to 212'. 09:00 - 12:00 3.00 DRILL DRLG SURFAC Drill f/ 212' to 349' MD, 349' TVD (137'), ADT 2.38 hrs, 5/7K WOB, 504 gpm @ 1100 psi, 65 RPM. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 13-1/2" Hole f/ 349' to 1,096' MD, 1,087' TVD (747'), ART= 2.66 hrs, AST= 6.69 hrs, ADT= 9.35 hrs., 560 gpm @ 1400 psi, WOB 20-25K, RPM 60- 70, UP 94K, DN 90K, ROT 89K, TO on 3500 ft/Ib, TO off 1500 ft/Ib, Ran GYRO #1 @ 50', 100', 200', 300', 355', #2 @ 443', #3 @ 533', Sliding 70' and Rotating 20' per stand, Mud wt 8.9, Vis 300. 11/2/2005 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill 13-1/2" Hole f/ 1,096' to 2,170' MD, 2,060' TVD (1,074'), ADT= 8.74 hrs, ART= 1.5 hrs, AST-- 7.24 hrs., 721 gpm @ 2100 psi, WOB 10-20K, RPM 75, UP 11 OK, DN 100K, ROT 105K, TO on 3000 ft/lb, TO off 2000 ft/lb, Sliding 70' and Rotating 20' per stand, Mud wt 8.9, Vis 300. 12:00 - 13:30 1.50 DRILL DRLG SURFAC Drill 13-1/2" Hole f/ 2,170' to 2,342' MD, 2,212' TVD (172'), ADT= 1.08 hrs, ART= 0.61 hrs, AST= 0.47 hrs., 763 gpm @ 2300 psi, WOB 0-25K, RPM 75, UP 120K, DN 104K, ROT 109K, TO on 5/ 6000 ft/lb, TO off 5000 ft/Ib, Mud wt 8.9, Vis 300. 13:30 - 14:00 0.50 DRILL CIRC SURFAC Circ btm's up at rate of 763 gpm @ 2300 psi, 80 RPM, TO 5500 fulb, Reciprocate pipe f/ 2,342' to 2,285' while circ. 14:00 - 17:00 3.00 DRILL TRIP SURFAC Back Ream out of hole at rate of 763 gpm @ 2300 psi, 80 RPM, 25 to 35 ft/min., Slowed down to 5 to 10 ft/min. and let hole clean up after Printed: 12/29/2005 9:54:06 AM Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 11/2/2005 114:00 - 17:00 1 3.001 DRILL ITRIP (SURFAC 17:00 -17:30 1 0.50 DRILL TRIP ISURFAC 17:30 - 19:30 2.00 DRILL JPULD ISURFAC 19:30 - 21:00 1.50 CASE IRLIRD SURFAC 21:00 - 00:00 1 3.00 I CASE I RUNC i SURFAC 11/3/2005 00:00 - 00:15 0.25 CASE RUNC SURFAC 00:15 - 00:45 0.50 CASE CIRC SURFAC 00:45 - 01:30 0.75 CEMEN�PULD NUND SURFAC 01:30 - 02:30 1.00 CEMEN CIRC SURFAC 02:30 - 05:30 3.00 CEMEN PUMP SURFAC 05:30 - 07:30 2.001 CEMENT PULD SURFAC 07:30 - 09:00 1.50 CASE RURD SURFAC 09:00 -11:00 2.00 WELCT NUND SURFAC 11:00 -13:15 2.25 WELCT NUND SURFAC 13:15 -16:30 3.25 WELCT NUND SURFAC 16:30 -18:00 1.50 WELCT BOPS SURFAC • Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: pulling 8 stands f/ 1,549' to 1,363' - Hole unloaded large amounts of Clay and Sand, Continue to Back Ream out to 895'- Hole cleaned up. POOH on elevators & rack back HWDP & Jars. Lay down BHA #1, NMDC's, UBHO sub, X/O, MWD, Motor, Bit. Rig to Run 10-3/4" Casing, Held PJSM with all personnel running casing. Run 55 its of 57 jts of 10 3/4", 45.5#, L-80 BTC csg to 2,225' per well plan, MU 10 3/4 weatherford Model 303 float shoe, 2 joints 45.5#, L-80, BTC csg and Weatherford model 402 FC, (1) joint 45.5#, L-80, BTC casing, baker locked btm 3 conn. and pumped thru checking float equipment, cont RIH with 10 3/4" csg to 2,225' at 00:00 hrs, Ran 19 bow spring centralizers on 1 st 17 its ran 1 cent on jt. # 56 @ 20" conductor @ 108' (Total of 20 centralizers and 3 stops). No problems RIH, st wt up 130K, down wt 11 OK Finish running 10-3/4" casing (Total 57 jts.), Pick up Vetco Gray casing hanger and land w/ Shoe @ 2,332.83', Float collar @ 2,249.12'. Circ btm's up, Stage rate up to 6.0 bpm @ 250 psi, Reciprocate pipe 10'-15' Up 130K, Dn 107K. Rig down Frank's fill up tool, Blow down top drive, Rig up Dowell cement head. Finish circ and cond mud for cementing, staged pump rate up to 6.5 bpm at 280 psi, reciprocating pipe 15' with 130K up wt and 107K do wt, circ and Gond mud to 8.9 ppg and lowered PV to 21 and YP to 16, held PJSM on cement job with Dowell, ASRC and rig crew while circ and cond mud. 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 bbis of CW 100 (50 bbls total), Followed by 50 bbis of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, Pumped 380.4 bbis (480 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.7 bpm at 225 psi, Followed with 63.7 bbis (145 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 4.4 bpm at 230 psi, reciptrocated csg 10 to 15' and had futl returns, shut down and dropped top plug, Kick plug out with 20 bbis fresh water. Rig displaced cement with 194.2 bbis (Total 214.2 bbis to bump) of 8.9 ppg mud, displaced cmt at 7.0 bpm, initial circ pressure 420 psi, max pressure 650 psi, Observed red dye at shakers after pumping 40.2 bbis mud, slowed rate to 3 bpm @ 425 psi and bumped plug, Pressured up to 1000 psi, held 5 min, checked floats and held, CIP @ 05:10 hrs 11/3/05, Reciprocated casing until 56 bbis Gement around shoe then pipe became tight and land pipe on hanger, Up 130K, Dn 107K, Float shoe at 2,332' and Float collar at 2,249' Had full returns during job with 58.3 bbls of 10.7+ ppg cmt back to surface- Note; Hanger plugged as cmt came to surface- picked pipe up 1" to unplug, then set back down - OK Flush out diverter system with fresh water, Wash cement from flow line & drip pans, Rig down Dowell cement head, Lay down landing joint. Rig down all casing tools, Clear rig floor. Nipple down Diverter system. Nipple up Vetco Gray 13-5/8" Wellhead & test to 5000 psi. Nipple up BOPE Rig & Test Lower 7-5/8" Rams, Annular, Choke valves 1, 12,13,14, Printed: 1 129r1UUb V:b4:L)b AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: • 1 J-164 1J-164 ROT - DRILLING nl334@ppco.com Doyon 141 11/3/2005 116:30 -18:00 1 1.501 WELC BOPE SURFAC BOPE JSURFAC BOPE ISURFAC BOPE SURFAC BOPE SURFAC BOPE SURFAC PULD SURFAC PULD SURFAC PULD SURFAC TRIP JSURFAC CIRC SURFAC DEQT SURFAC DRLG SURFAC 16:15 -16:45 1 0.501 DRILL I CIRC I SURFAC 16:45 -17:30 1 0.751 DRILL I LOT I SURFAC 17:30 - 00:00 I 6.501 DRILL 1 DRLG I INTRMI 111/5/2005 100:00 - 12:00 1 12.001 DRILL I DRLG I INTRMI 12:00 - 00:00 1 12.001 DRILL I DRLG 1 INTRMI 11/6/2005 100:00 - 00:30 00:30 - 01:15 01:15 - 01:45 01:45 - 02:45 02:45 - 05:00 0.501 DRILL I DRLG I INTRMI 0.75 DRILL CIRC INTRMI 0.50 DRILL DRLG INTRMI 1.001 DRILL ;CIRC I INTRMI 2.251 DRILL (TRIP I INTRMI • Spud Date: 11/1/2005 Start: 10/3112005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: HCR Kill, 5" Inside dart to 250 psi Low & 3500 psi High, Note: Upper Varible Rams Failed Test. AOGCC Chuck Scheve waived test. Open top doors on BOP Stack and remove 3-1/2"x 6" varible Rams. Continue testing ROPE, Annular w/ 5", Manule Kill valves 4,5,6,7,8,9,10,11, 5" floor safety valve, Upper IBOP. Open top doors on BOP & Install 3-1/2" x 6" varible Rames. Continue testing BOPE, Top Rams wl 4" & 5", Lower IBOP, Manule Choke valves 2 & 3, 4" Floor valves, Blind Rams, Annular w/ 4", HCR Choke, Choke valves 2 & 3, Rig down test equip. Install wear bushing. Change top drive saver sub to 4" XT -39. Pick up 35 stands 4" drill pipe and stand back in derrick. Make up 9-7/8 MXC1 Bit, Motor w/ 1.5 deg. bend, Stab, Float sub, MWD, Orient same, GR/RES/PWD/HCIM/ACAL/TM HOC, Up toad MWD tools, NMDC's, Surface test MWD- OK. RIH & Tag Float collar @ 2249'. Circ btm's up at rate of 600 gpm @ 1800 psi. Rig & Test 10-314" casing to 3000 psi f/ 30 min:- OK. Drill out Float Collar @ 2,249', Cement, Float Shoe @ 2,332' and drill 20' new hole to 2,362', 600 gpm @ 1700 psi, 50 RPM, TQ 5K. Pump Hi -vis weighted sweep, Change over to LSND Mud, Had 511 unA gays on bW& up, Cric hole clean w/ 650 gpm @ 2000 psi, 50 RPM, TQ 6K. Rig & Perform LOT of 15.4 EMW W 9.0 ppg mud, 737 psi Q 2202' TVD. Drill 9-7/8" Hole f/ 2,362' to 3,063' MD, 2,831' TVD (701'), ADT= 3.43 hrs, ART= 1.22 hrs, AST= 2.21 hrs, WOB 5-10K, 606 gpm @ 1900 psi, 85 RPM, TO on 6 to 8,000 ft/lb, Up 130K, On 91K, ROT 105K, Pump 1 Hi -vis weighted sweep w/ 20% increase in cuttings, Max ECD's 9.65, Max gas 58 units. Drill 9-7/8" Hole f/ 3,063' to 4,184' MD, 3,423' TVD (1121'), ADT= 9.91 hrs, ART= 6.28 hrs, AST= 2.91 hrs, WOB 5-20K, 625 gpm @ 2580 psi, 85 RPM, Up 127K, On 85K, ROT 101 K, TQ on btm 6 to 7,000 ft/lb, TQ off btm 6 to 7,000 ft/lb, Pump 2 Hi -vis weighted sweeps w/ 20% increase in cuttings on 1st one and 10% on the 2nd, Max ECD's 9.7, Max gas 78 units. I Drill 9-7/8" Hole f/ 4,184' to 5,226" MD, 3,632' TVD (1042'), ADT-- 8.76 hrs, ART= 5.85 hrs, AST= 2.91 hrs, WOB 5-25K, 657 gpm @ 2850 psi, 85 RPM, Up 109K, On 83K, ROT 94K, TQ on btm 6500 ft/lb, TQ off btm 5500 ft/lb, Pump 1 Hi -vis weighted sweep w/ 10% increase in cuttings, Max ECD's 10.0, Max gas 155 units. Drill 9-7/8" Hole f/ 5,226' to 5,305' MD, 3,648' TVD (79'), ADT= 0.36 hrs, ART= 0.36 hrs, AST= 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, On 83K, ROT 94K, TQ on btm 6500 ft/lb, TQ off btm 5500 ftllb, Max ECD's 10.1. Pump Hi -vis weighted sweep & Circ 2 x Btm's up to evaluate logs. Drill 9-7/8" Hole f/ 5,305' to 5,358' MD, 3,656' TVD (53'), ADT= 0.36 hrs, ART= 0.36 hrs, AST-- 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, On 83K, ROT 94K, TQ on btm 6500 ft/lb, TQ off btm 5500 ft/Ib, Max ECD's 10.1. Circ 2 x Btm's up at rate of 655 gpm @ 2800 psi w/ 85 RPM, TQ 5000 ft/lb. Monitor well, Back Ream out of hole f/ 5,358' to 4187' at drilling rate of Printed: 12/29/2005 9:54:06 AM 18:00 - 19:00 1.00 WELC 19:00 - 20:15 1.25 WELC 20:15 - 21:00 0.75 WELC 21:00 - 00:00 3.00 WELC 11/4/2005 00:00 - 01:00 1.00 WELC 01:00 - 03:00 2.00 DRILL 03:00 - 08:00 5.00 DRILL 08:00 - 12:00 4.00 DRILL 12:00 - 13:30 1.50 DRILL 13:30 - 14:00 0.50 DRILL 14:00 -15:15 1.25 DRILL 15:15 - 16:15 1.00 DRILL BOPE SURFAC BOPE JSURFAC BOPE ISURFAC BOPE SURFAC BOPE SURFAC BOPE SURFAC PULD SURFAC PULD SURFAC PULD SURFAC TRIP JSURFAC CIRC SURFAC DEQT SURFAC DRLG SURFAC 16:15 -16:45 1 0.501 DRILL I CIRC I SURFAC 16:45 -17:30 1 0.751 DRILL I LOT I SURFAC 17:30 - 00:00 I 6.501 DRILL 1 DRLG I INTRMI 111/5/2005 100:00 - 12:00 1 12.001 DRILL I DRLG I INTRMI 12:00 - 00:00 1 12.001 DRILL I DRLG 1 INTRMI 11/6/2005 100:00 - 00:30 00:30 - 01:15 01:15 - 01:45 01:45 - 02:45 02:45 - 05:00 0.501 DRILL I DRLG I INTRMI 0.75 DRILL CIRC INTRMI 0.50 DRILL DRLG INTRMI 1.001 DRILL ;CIRC I INTRMI 2.251 DRILL (TRIP I INTRMI • Spud Date: 11/1/2005 Start: 10/3112005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: HCR Kill, 5" Inside dart to 250 psi Low & 3500 psi High, Note: Upper Varible Rams Failed Test. AOGCC Chuck Scheve waived test. Open top doors on BOP Stack and remove 3-1/2"x 6" varible Rams. Continue testing ROPE, Annular w/ 5", Manule Kill valves 4,5,6,7,8,9,10,11, 5" floor safety valve, Upper IBOP. Open top doors on BOP & Install 3-1/2" x 6" varible Rames. Continue testing BOPE, Top Rams wl 4" & 5", Lower IBOP, Manule Choke valves 2 & 3, 4" Floor valves, Blind Rams, Annular w/ 4", HCR Choke, Choke valves 2 & 3, Rig down test equip. Install wear bushing. Change top drive saver sub to 4" XT -39. Pick up 35 stands 4" drill pipe and stand back in derrick. Make up 9-7/8 MXC1 Bit, Motor w/ 1.5 deg. bend, Stab, Float sub, MWD, Orient same, GR/RES/PWD/HCIM/ACAL/TM HOC, Up toad MWD tools, NMDC's, Surface test MWD- OK. RIH & Tag Float collar @ 2249'. Circ btm's up at rate of 600 gpm @ 1800 psi. Rig & Test 10-314" casing to 3000 psi f/ 30 min:- OK. Drill out Float Collar @ 2,249', Cement, Float Shoe @ 2,332' and drill 20' new hole to 2,362', 600 gpm @ 1700 psi, 50 RPM, TQ 5K. Pump Hi -vis weighted sweep, Change over to LSND Mud, Had 511 unA gays on bW& up, Cric hole clean w/ 650 gpm @ 2000 psi, 50 RPM, TQ 6K. Rig & Perform LOT of 15.4 EMW W 9.0 ppg mud, 737 psi Q 2202' TVD. Drill 9-7/8" Hole f/ 2,362' to 3,063' MD, 2,831' TVD (701'), ADT= 3.43 hrs, ART= 1.22 hrs, AST= 2.21 hrs, WOB 5-10K, 606 gpm @ 1900 psi, 85 RPM, TO on 6 to 8,000 ft/lb, Up 130K, On 91K, ROT 105K, Pump 1 Hi -vis weighted sweep w/ 20% increase in cuttings, Max ECD's 9.65, Max gas 58 units. Drill 9-7/8" Hole f/ 3,063' to 4,184' MD, 3,423' TVD (1121'), ADT= 9.91 hrs, ART= 6.28 hrs, AST= 2.91 hrs, WOB 5-20K, 625 gpm @ 2580 psi, 85 RPM, Up 127K, On 85K, ROT 101 K, TQ on btm 6 to 7,000 ft/lb, TQ off btm 6 to 7,000 ft/lb, Pump 2 Hi -vis weighted sweeps w/ 20% increase in cuttings on 1st one and 10% on the 2nd, Max ECD's 9.7, Max gas 78 units. I Drill 9-7/8" Hole f/ 4,184' to 5,226" MD, 3,632' TVD (1042'), ADT-- 8.76 hrs, ART= 5.85 hrs, AST= 2.91 hrs, WOB 5-25K, 657 gpm @ 2850 psi, 85 RPM, Up 109K, On 83K, ROT 94K, TQ on btm 6500 ft/lb, TQ off btm 5500 ft/lb, Pump 1 Hi -vis weighted sweep w/ 10% increase in cuttings, Max ECD's 10.0, Max gas 155 units. Drill 9-7/8" Hole f/ 5,226' to 5,305' MD, 3,648' TVD (79'), ADT= 0.36 hrs, ART= 0.36 hrs, AST= 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, On 83K, ROT 94K, TQ on btm 6500 ft/lb, TQ off btm 5500 ftllb, Max ECD's 10.1. Pump Hi -vis weighted sweep & Circ 2 x Btm's up to evaluate logs. Drill 9-7/8" Hole f/ 5,305' to 5,358' MD, 3,656' TVD (53'), ADT= 0.36 hrs, ART= 0.36 hrs, AST-- 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, On 83K, ROT 94K, TQ on btm 6500 ft/lb, TQ off btm 5500 ft/Ib, Max ECD's 10.1. Circ 2 x Btm's up at rate of 655 gpm @ 2800 psi w/ 85 RPM, TQ 5000 ft/lb. Monitor well, Back Ream out of hole f/ 5,358' to 4187' at drilling rate of Printed: 12/29/2005 9:54:06 AM Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 11/6/2005 02:45 - 05:00 2.25 DRILL TRIP INTRM1 650 gpm @ 2800 psi w/ 85 RPM, Pulling speed of 35 to 45 ft/min. Slowed pulling speed to 3-5 ft/min. while circ 2 x Btm's up & hole clean f/ 4,187' to 4000'. 05:00 - 06:30 1.50 DRILL TRIP INTRMI Monitor well, POOH w/ 3 std's to check f/ swabbing -OK, Pump dry job, POOH to Shoe @ 2332' (Hole in very good shape). 06:30 - 09:15 2.75 DRILL TRIP INTRMI POOH & Lay down 5" drill pipe, 5" HWDP & Jars. 09:15 - 11:15 2.00 DRILL TRIP INTRM1 Lay down NMDC's, Down load MWD tools, Lay down remainder of BHA #2. 11:15 - 12:00 0.75 DRILL PULD INTRMI Lay down BHA tools from rig floor, Clean rig floor. 12:00 - 14:30 2.50 CASE RURD INTRM1 Pull wear bushing (1 hr. to pull), Rig to run 7-5/8" casing. 14:30 -17:15 2.75 CASE RUNC INTRM1 Ran 7 5/8" Weatherford float shoe, 2 its 7 5/8", 29.7#, L-80, BTCM csg, float shoe and thread locked btm 3 conn, circ thru float equip and ck ok, RIH with 7 5/8" csg to 2,315', Ran 60 tandem rise centralizers on 1st 60 its, 1-5' above shoe over stops & 1 -10' above and below float collar, the remaining over collars, did not run any centralizers on both window its. 17:15 -17:45 0.50 CASE CIRC INTRMI Circ btm's up, Stage rate f/ 3 bpm @ 300 psi to 5 bpm @ 350 psi. 17:45 - 20:30 2.75 CASE RUNC INTRM1 RIH w/ 7-5/8" csg to 3,860' with no problems, Break circ at rate of 3 bpm @ 500 psi -OK, Continue to RIH & Tag btm @ 5,358' 20:30 - 21:00 0.50 CEMENI PULD INTRMI Rig down Frank's fill up tool, Blow down top drive, Rig up Dowell cement head. 21:00 - 23:00 2.00 CEMENI CIRC INTRM1 Circ & Cond. mud, Stage rate up f/ 3.5 bpm @ 450 psi to 6.5 bpm @ 425 psi, Reciprocate pipe 30 to 35' while circ Up 160K, Dn 95K. Held PJSM w/ all rig personnel for cement job, initial MW out, 9.9 ppg, 75 vis, PV 18, YP 22, Conditioned mud to final MW of 9.2 ppg, 44 vis, PV 7and PVof13. 23:00 - 00:00 1.00 CEMENI PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4 bpm @ 550 psi, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100 at rate of 4 bpm @ 570 psi, Pumped 50 bbls of MudPush at 11.0 ppg at rate of 4.0 bpm @ 550 psi, Dropped btm plug then pumped 92.3 bbls, (230 sxs -10% over caliper) of DeepCreta cgtt at, 12.5 ppg, 2.28 yield with additives, eve 4.8 bpm at 550 psi, Reciprocated pipe with full returns 30' to 35'. Drop top plug and Dowell kicked top plug out with 10 bbfs fresh water. 11/7/2005 00:00 - 01:00 1.00 CEMENI PUMP INTRM1 Rig displaced cement with 9.0 ppg OBM, Bumped plug after pumping 234.2 bbis OBM (Total of 244.2 bbis) (96% pump eff.) ave 7 bpm while displacing cmt, Observed lift pressure f/ 500 psi to 800 psi prior to slowing pump rate to 3 bpm, Slowed pump rate to 3 bpm @ 550 psi with 10 bbls left to pump and bumped plug to 1100 psi, ck floats and held. CIP at 01:00 hrs, 11-7-05. Reciprocated pipe 30' to 35' until MudPUSH at shoe, then recap. 20' until Cmt at shoe, then recip. 10' until tact 30 bbls, then recip. 5' until last 10 bbls then stopped pipe, Landed csg with Shoe @ 5358', Float Collar @ 5268', Calc TOC @ 3052', Had full returns thru out job. Well static after shut down. 01:00 - 01:15 0.25 CEMENTPULD INTRMI Rig down cement head and equip. 01:15 - 04:30 3.25 CASE NUND INTRMI Installed 7-5/8" csg slips, Set slips with 60K over string weight (150K on slips), Cut off csg and LD cut off it and installed pack -off, Test Packoff to 250 low & 3500 psi high f/ 10 min. 04:30 - 04:45 0.25 CASE OTHR INTRMI Install wear bushing. 04:45 - 05:45 1.00 DRILL LOT INTRMI Rig & at 05:00 hrs. Perform LOT on 10-3/4"x 7-W ark" lus of 440 psi, 9.2 ppg mud, 2202' TVD @ 10-3/4" shoe, = 13.0 ppg EMW used 5 bbls to perform test., Pump additional 25 bbis down annulus to, Insure no cement in annulus at rate of 2 bpm @ 680 psi. ,05:45 - 09:15 3.50 DRILL PULD INTRMI 1 PJSM, Pick up & RIH w/ 120 its. 4" drill pipe, Note; At 07:00 hrs, Printed: 12/29/2005 9:54:06 AM Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 11/7/2005 105:45 - 09:15 1 3.501 DRILL I PULD I INTRMI 09:15 -10:15 1.00 DRILL IPULD JINTRMI 10:15 - 18:00 1 7.75 DRILL 1PULD IINTRMI 18:00 - 21:00 1 3.001 DRILL 1 PULD I INTRMI 21:00 - 00:00 1 3.001 DRILL I PULD I INTRM1 11/8/2005 100:00 - 00:45 1 0.751 DRILL 1 PULD I INTRMI 00:45 - 03:30 2.75 DRILL TRIP INTRMI 03:30 - 04:00 0.50 DRILL TRIP INTRM1 04:00 - 04:30 0.50 CEMENI DSHO INTRM1 04:30 - 05:30 1.00 DRILL CIRC INTRM1 05:30 - 06:45 1.25 RIGMNT RSRV INTRM1 06:45 - 07:45 1 1.001 CASE DEQT INTRM1 07:45 -11:00 I 3.251 CEMENTDSHO I INTRM1 11:00 - 12:00 I 1.001 DRILL I CIRC I INTRM1 12:00 -12:30 1 0.501 DRILL I LOT I INTRMI 12:30 - 00:00 1 11.501 DRILL 1 DRLG I PROD 11/9/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Flushed 10-3/4"x 7-5/8" annulus with 120 bbls fresh water at rate of 2 bpm @ 660 psi (Total 150 bbls fresh water to flush annulus). Pick up Lo -Tad's and Sliders to rig floor f/ beaver slide. POOH picking up Lo -Tads (1 per std.) & Slides (3 per stand) & Rack back same, Note: At 10:23 hrs, Rig tittle red service aild'freeze protect IG-W4"x 7-516" annulus with 85 bb{s diesel. Pick up & RIH wl 7 stands 4" HWDP, 6 stands 4-3/4" DC's & 4" HWDP Hybrid Push pipe, POOH & Stand back same. Make up BHA #3, 6-3/4" Bit, 4-3/4" 5200 GeoPiolt, NM Pony collar, DM collar, Stab, MWD tools, NMDC's, 1-HWDP, Jars, 4- HWDP, Upload MWD tools, Surface test MWD tools. Continue Make up BHA # 3. Make up 1 - jnt 4 1/2" Non Mag flex drill collar ( 30.79'), Crossover ( 1.07'), 1 - 4" HWDP ( 30.33'), 4 3/4" Drilling Jars ( 28.59'), and 4 - 4" HWDP ( 120.96'). Jars = 60.55 HRS to start. Trip in hole from 367'- 3908'( 3541), picking up singles of 4" DP XT -39 from pipe shed. Continue trip in hole running from derrick from 3908'- 5241'( 1333') to tag cement at 5241'. Drill hard cement from 5241'- 5268'( 27'). Drill with 60 RPM's @ 3K torque, 250 GPM's - 1550 PSI. PU WT = 100K, SO WT = 75K, ROT WT = 85K. Circulate bottoms up @ 60 SPM, 250 GPMs - 1400 PSI. RU and Slip & Cut 60' of drilling line. Inspect brakes, and service Top Drive. RU & test casing to 3000 PSI for 30 minutes. Record on chart. Good Test. Bleed pressures and RD test equipment. Drill out Float equipment and shoe track f/ 5268' to 5358' and 20' of new hole from 5358'- 5378'. Parameters @ 70 SPM - 250 GPM's -1900 PSI. 60 RPM'S - 3K Torque. ART =.59 HRS. Circulate Bottoms up @ 330 GPM's - 3000 PSI. 92 SPM, Reciprocating & rotate drill string 60 RPM's - 3k Free torque. PU WT = 100K, SO WT = 75K, ROT WT = 85K. Jars @ 61.14 Total HRS, Bit Hrs =.59. Mud WT = 9.0 PPG, YP = 18, Visc = 90 RU & and pump down drill pipe annulus to perform LOT to EMW of 14.9 PPG w/ 9.0 ppg mud, 1123 psi & 3656' TVD. Bleed Directional drill 6 3/4" Hole in the "A" Lateral from 5378' - 6711'( 1333'). TVD = 3671'. ART = 7.36 HRS, PU WT = 106K, SO WT = 66K, ROT WT = 84K, Torque off btm = 4K, Torque on bottom = 4.5K. WOB = 5-7K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3025 PSI. Total Jar Hrs = 68.5 Total Bit Hrs = 7.95 ECD at 10.6 PPG. Mud WT = 9.0 PPG Viscosity = 82, YP = 17. SPR's @ 6338' MD, 3670' TVD. Pump #1 - 25 SPM - 440 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 440 PSI, 35 SPM - 640 PSI. Survey @ 6583' MD , 3670 TVD - Inc = 89.10 Deg. AZ = 3.31 Deg. MAX GAS = 65 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% increase in cuttings when sweep returned. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 6711,'- 8411 711'- 8411 (1700'). TVD = 3690'. ART = 8.32 HRS, PU WT = 107K, SO WT = 68K, ROT WT = 84K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3100 PSI. Total Jar Hrs = 76.82 Total Bit Hrs = 16.60 ECD at 11.1 PPG. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. SPR's @ 7772' MD, 3696' TVD. Pump #1 - 25 SPM - 490 PSI, 35 SPM - 690 PSI. Pump #2 Printed: 12/29/2005 9:54:06 AM Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 11/9/2005 100:00 - 12:00 1 12.001 DRILL I DRLG TROD 12:00 -13:00 1 1.001 DRILL I DRLG I PROD 13:00 - 13:15 0.25 DRILL �OTHR PROD 13:15 - 16:15 3.00 DRILL DRU G PROD 16:15 - 16:30 1 0.251 DRILL I OTHR I PROD 16:30 - 18:15 I 1.751 DRILL I DRLG I PROD 18:15 - 18:45 1 0.501 DRILL I OTHR I PROD 18:45 - 00:00 1 5.251 DRILL I DRLG TROD 11/10/2005 100:00-12:00 I 12.001 DRILL 1 DRLG TROD Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: - 25 SPM - 490 PSI, 35 SPM - 700 PSI. Survey @ 8220' MD , 3687 TVD - Inc = 86.66 Deg. AZ = 359.29 Deg. MAX GAS = 57 Units. Pumping weighted sweeps to control ECD and clean hole @ 7192', 7390', 7582', 8260'. Observe 10% - 20% increases in cuttings when sweep returned. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 841 V- 8617' (206'). TVD = 3696'. ART = 1.0 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM'S = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3100 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 69 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. Stop drilling for Geologists to evaluate logs. Crossed fault @ 8855 MD 3710 TVD. Observed fault bigger than expected. 50' Throw. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 8617'- 8933- (316'). TVD = 3711'. ART = 2.05 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM'S = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3200 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 71 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. Also observed bigger sized shale cuttings in sweep. Stop drilling for Geologists to evaluate logs with town, as we went from sand to shale. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 8933' - 9127' (194'). TVD = 3702'. ART =.90 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3400 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 71 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. Stop drilling for Geologists to evaluate logs with town on orders for proceeding. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 9127'- 9752- (626). TVD = 3674'. ART = 3.52 HRS, PU WT = 129K, SO WT = 56K, ROT WT = 85K, Torque off btm = 5.5K, Torque on bottom = 5.5K. WOB = 5-20K, RPM's = 130 -140, Pumps @ 93 SPM, 330 GPM's - 3400 PSI. Total Jar Hrs = 84.29 Total Bit Hrs = 24.07 ECD at 11.5 PPG. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. Gels @ 19/27. SPR's @ 9707' MD, 3672' TVD. Pump #1 - 25 SPM - 550 PSI, 35 SPM - 750 PSI. Pump #2 - 25 SPM - 540 PSI, 35 SPM - 760 PSI. Survey @ 9671' MD , 3678 TVD - Inc = 92.18 Deg. AZ = 3.04 Deg. MAX GAS = 169 Units. BGG = 48 units. Pumping weighted sweeps to control ECD and clean hole @ 9513'. Observe 10% - 20% increases in cuttings when sweep returned. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 9752' - 10971' (1219'). TVD = 3718'. ART = 7.10 HRS, PU WT = 145K, SO WT = 45K, ROT WT = 89K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 5-10K, RPM's = 130, Pumps @ 93 SPM, 330 GPM's - 3650 PSI. Total Jar Hrs = 91.39 Total Bit Hrs = 31.41 ECD at 12.19 PPG. Mud WT = 9.0 PPG Viscosity = 71, YP = 19. Gels @ 20/30. SPR's @ 10673' MD, 3702' TVD. Pump #1 - 25 SPM - 690 PSI, 35 SPM - 860 PSI. Pump #2 - 25 SPM - 690 PSI, 35 SPM - 850 PSI. Survey @ 10911' MD , 3718 TVD - Inc = 88.68 Deg. AZ = 356.33 Deg. Printed: 12/29/2005 9:54:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1J-164 U-164 ROT - DRILLING nl334@ppco.com Doyon 141 11/10/2005 100:00 - 12:00 1 12.001 DRILL 1 DRLG I PROD 12:00 - 15:15 15:15 -16:45 16:45 - 20:00 20:00 - 00:00 11/11/2005 00:00 - 01:00 01:00 - 04:00 04:00 - 04:15 04:15 - 06:30 06:30 - 08:00 08:00 - 12:00 12:00 - 13:00 13:00 - 13:45 13:45 - 14:30 14:30 - 15:30 3.251 DRILL I DRLG TROD 1.50 DRILL CIRC PROD 3.25 DRILL WIPR PROD 4.00 DRILL WIPR PROD 1.00 DRILL CIRC PROD 3.001 DRILL I WIPR I PROD 0.25 DRILL REAM PROD 2.25 DRILL CIRC PROD 1.50 DRILL CIRC PROD 4.00 DRILL TRIP PROD 1.00 DRILL TRIP PROD 0.75 DRILL PULD PROD 0.75 DRILL OTHR PROD 1.00 DRILL PULD PROD Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: MAX GAS = 132 Units. Pumping weighted sweeps to control ECD and clean hole @ 9822', 10094', 10190', 10382'. Observe 10% - 20% increases in cuttings when sweep returned. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 10971' - 11400 MD (429'). TVD = 3742'. ART = 2.59 HRS, PU WT = 150K, SO WT = 60K, ROT WT = 93K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 5-1 OK, RPM's = 130, Pumps @ 93 SPM, 330 GPM's - 4000 PSI. Total Jar Hrs = 94.22 Total Bit Hrs = 34.0, ECD at 12.30 PPG. Mud WT = 8.9+ PPG Viscosity = 75, YP = 19. Gels @ 21/28. SPR's @ 11400' MD, 3745' TVD. Pump #1 - 25 SPM - 860 PSI, 35 SPM - 1080 PSI. Pump #2 - 25 SPM - 860 PSI, 35 SPM - 1080 PSI. Survey @ 11400' MD , 3745.43 TVD - Inc = 86.38 Deg. AZ = 358.75 Deg. MAX GAS = 104 Units. Pumping weighted sweeps to control ECD and clean hole @ 11320'. Observe 10% - 20% increases in cuttings when sweep returned. Pump 35 BBLS Hi Visc weighted sweep, and two bottoms up @ 93 SPM, 330 GPM - 4000 PSI. Rotate & Reciprocate drill string @ 130 RPM's with 6K torque. Obtain SPR's. Monitor well - Static. POOH on elevators observiing well taking proper hole fill and normal drag of 15 - 20K from 11400'- 7939'(3461'). Observed little overpull @ 9175' and weight fell off. At 7939' observed 20K overpull, 3 times. Attempt to wipe through spot without success. Screw into TO and BROOH from 7939'- 5358'(2581') = Shoe depth. Back ream at 93 SPM, 330 GPM's - 3150 PSI. RPM's of 130 with 6K torque. PU WT = 95K, SO WT = 75K, ROT WT = 85K @ 5850'. Pump a 35 BBL Hi Visc weighted sweep @ 93 SPM, 330 GPM - 2700 PSI, and 3 Bottoms up to observe 10-15% increase in cutting when sweep returned. Trip back in hole on elevators, observing clean hole conditions, and filling drill string every 25 stands. We did not need to pump into the hole as we had downweight of 55-60K. Make up top drive, wash & ream from 11259'-1 1400' ( 141'). Pumps @ 93 SPM, 330 GPM - 3950 PSI. Pump a 35 BBL Hi Visc sweep @ 93 SPM, 330 GPM - 3950 PSI, and 2 bottoms up observing 10% increase in cuttings at shakers and cleaned up. PU WT = 140K, SO WT = 65K, ROT WT = 65K, RPM's at 130 with 3-5K torque. Displace well from 8.9 PPG MOBM, to 8.8+ PPG SFMOBM, at 7 BPM - 84 SPM - 4000 PSI. Observed good displacement, no spills. Obtain SPR's @ 11395' MD, 3745' TVD. Pump #1 = 25 SPM - 610 PSI. 35 SPM - 830 PSI. Pump #2 = 25 SPM - 650 PSI. 35 SPM - 840 PSI. Monitor well - static. POOH on elevators observing good clean hole conditions taking proper hole fill. Monitor well @ shoe 5358', static. Continue POOH to 2048'. ( 9352'). Continue POOH from 2048'- 366'( 1682'). Rack back in derrick 4 jnts 4" HWDP ( 102.96'), 4 3/4" Drilling Jars 28.59'), 1 - jnt 4" HWDP ( 30.33'), crossover ( 1.07'), 3 - NMFC's (92.80'), breakout & lay down 4.688" Integral Blade Stabilizer ( 5.46'). Plug in and download MWD assembly. Continue breakout & lay down remaining BHA. Lay down 4 3/4" TM hang off collar ( 10.90'), 4 3/4" PWD collar ( 10.73'), 4 3/4" Slimphase 4 w/ DGR & EWR ( 24.18), 4.3/4" Smart Stabilizer ( 3.59'), 4 314" DM Collar ( 8.56'), 4 3/4" GP NM Flex Pony collar ( 11.54'), 5200 series Printed: 12/29/2005 9:54:06 AM Legal Well Name: U-164 Common Well Name: U-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 11/11/2005 14:30 - 15:30 1.00 DRILL PULD PROD Geo -Pilot ( 16.20 and Security DBS 6 3/4" FM2641 Bit ( 1.26). Bit grade@ 1 /1 /RG/N/0/1/NO/TD. 15:30 - 16:00 0.50 DRILL RIRD CMPLTN Clean and clear rig floor area, lay down tools. 16:00 - 17:45 1.75 LOG RURD CMPLTN PJSM with entire crew and SWS wireline crew. Discuss Safety issues and procedure. Rig up SWS wireliners, pull tools to rig floor, Make up USIT bond logging tools and test same. 17:45 -18:15 0.50 LOG ELOG CMPLTN Wirline in hole to 700' WLM, observe loss of telemetry. No Communication with tools. 18:15 - 20:00 1.75 LOG ELOG CMPLTN WLOH with tools. Inspect & trouble shoot same. Observe "Knuckle Joint" on Centralizer failed and flooded tool. Remove Knuckle Joint and replace Centralizer. Test tools. OK 20:00 - 00:00 4.00 LOG ELOG CMPLTN WLIH with UStT bond toggingtools to locate and log form 52W - 30t30'. Logs hx#ceted TOC @ 33W. effective TOC @ 3450'. 11/12/2005 00:00 - 00:15 0.25 LOG ELOG CMPLTN Continue with USIT bond log. Logged from 5280'- 3080'. Logs indicated TOC @ 3360'. Effective TOC @ 3450'. Sent copy of logs to town engineer. 00:15 - 02:00 1.75 LOG RURD CMPLTN WLOH with tools, and lay down same. Rig down all logging equipment, and tools. Clear floor area. 02:00 - 02:30 0.50 CASE RURD CMPLTN Pull tools to floor and Rig up casing running equipment. Verify all equipment in pipe shed ready to run. 02:30 - 02:45 0.25 CASE SFTY CMPLTN PJSM with entire crew. Discuss safety, and liner running procedure. 02:45 - 09:30 6.75 CASE PULR CMPLTN Pick up 4 1/2" L80, 12.6# IBT slotted / blank liner assembly and RIH. Make up torque =3000 Ft/lbs. Run liner as per detail. MU Blank joint with ROT Silver Bullet Guide shoe and pup. Continue with blanks and slots space out as per engineer, with Swell packers installed @ 8555', and 9072'. Run 214 Jnts = 6696.97', with Spiral glider centralizers floating on each int except the Constrictor packer jnts. ( 177 total) 09:30 - 10:30 1.00 CASE PULR CMPLTN Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running tools. 17 Total Constrictor packers run. Total BHA length of liner assembly = 6707.90'. PU WT = 85K, SO WT = 65K. 10:30 - 12:00 1.50 CASE RUNL CMPLTN Continue RIH with Liner on Drill Pipe from 6708'- 8341' ( 1633'). PU WT = 92K, SO WT = 66K. Observed no issues when going through shoe area into open hole. 12:00 - 14:30 2.50 CASE RUNL CMPLTN Continue RIH with Liner on Drill Pipe from 8341'- 11400'(3059'). Observed string taking weight at depths of 10280', 10644', 10915'and 11005' having to work free each time to free up and RIH to tag bottom @ 11413' Liner Measurements. Position string with Guide Shoe at ' planned depth of 11400'. Constrictor Packer depths area as follows, Jnt # 7 - 11175', Jnt # 25 - 10615', Jnt # 36 - 10285', Jnt # 52 - 9785', Jnt # 55 - 9685', Jnt# 63 - 9445', Swell Packer @ 9072', and 8555', Jnt # 104 - 8125', Jnt # 115 - 7785', Jnt # 124 - 7505', Jnt # 146 - 6845', Jnt # 161 - 6383', Jnt # 171 - 6055', Jnt # - 179 - 5804', Jnt # 183 - 5708', Jnt # 187'- 5565', Jnt # 191 - 5445', and Jnt # 193 - 5375'. 14:30 - 15:15 0.75 CASE OTHR CMPLTN Lay down 1 Lo -Tad in connection at rig floor. PU WT = 140K, SO WT = 70K. Drop 1 1/2" ball, chasing with pump to 400 stks and pressure up to 2000 PSI. Set down 55K to set slips as per BOT rep, continue pressure up to 4200 PSI, to complete setting PKR. Bleed pressure and pull up to 115K allowing "dogs" to kick out. Re -Tag liner top to verify for space out. Liner top = 4703.62'. 15:15 - 16:30 1.25 CASE CIRC CMPLTN Rig up and pressure test down annulus to test PKR at 1000 PSI - 5 Minutes. Stand back one stand and CBU - 2000 STks @ 63 SPM -1000 PSI. Blow down Top Drive and Kill Line. Monitor well - Static. Printed: 12/29/2005 9:54:06 AM Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 11/1212005 16:30 - 21:30 21:30 - 22:30 22:30 - 00:00 11/13/2005 00:00 - 01:45 • 1 J-164 1J-164 ROT - DRILLING nl334@ppco.com Doyon 141 5.00 CASE RUNL CMPLTN 1.00 CASE KURD CMPLTN 1.50 WINDO THR CMPLTN I 1.75 WINDOWPULD PROD2 01:45 - 02:45 1 1.00 1 WI 02:45 - 03:15 1 0.501 W1 03:15 - 05:45 2.50 WI 05:45 - 06:45 1.00 WI 06:45 - 07:30 0.75 WI 07:30 - 08:15 0.75 08:15 -12:00 3.75 12:00 - 12:45 0.75 W1 12:45 -13:45 1.00 WI 13:45 - 15:30 1.75 WI 15:30 -16:00 0.50 WI 16:00 -16:30 1 0.501 WIN PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 0 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: POOH, breakout and lay down all 40 Lo -Tads on drill string, leaving 30 stands of Sliders on Drillers side, and 10 stands of Slick DP on Off Drillers Side. Make Breaks, inspect BOT running tool assembly. Clean up all Lo -Tads, drained and wiped off for Target Zero, and remove from Rig Floor area. Clean & Clear floor, and lay down BOT running tools. PJSM with entire crew and BOT rep, Sperry Sun MWD & DD. Discuss Safety issues, and whipstock pick up procedure. Change elevators and pull tools to rig floor. PJSM with entire crew & BOT rep. Discuss Safety Issues and Whipstock Make up Procedure. Make up Whipstock assembly & space out pipe. MU Seal Assembly with Stop Sub ( 1.92'), 4 5/8" Unloader Sub ( 5.20'), 2 - 3 112 IF pups (11.85', 4.75'), 2-jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.08'),Bottom Trip Anchor (3.22'), Safety Disconnect (2.70'), Ported Drain Sub (1.02'), Debris Barrier sub w/ Cup (1.69'), & 5/8" Whipstock slide (15.47'). 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.51'), 6.750" Upper mill (5.82'), 1 -jnt 3 1/2" HWDP (29.8'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (24.18'), TM HOC (10.90'),2 - 4 3/4" Bumper jars (7.84', 7.57'). Plug in and Up load MWD assembly. Make up 2 stands of Hybrid Drill Collars (180.94') and Crossover (1.07') and MU Top Drive. Perform shallow pulse test on MWD with 78 SPM - 850 PSI, 275 GPM's. Good Test TIH at 2 minutes / stand as per BOT rep, from 395'- 4259'. (3864). Perform Mad Pass from 4259'- 4325'(66') as per GEO @ 86 SPM - 300 GPM , 1850 PSI. Orient whipstock face to 8 degrees left of high side while Mad Pass. Continue TIH from 4326- 4703'( 378'). PU WT = 125K, SO WT = 114K. Orient Whipstock face to 5 Degrres left of high side as per DD & Co. Rep. Tag top of A2 liner @ 4703' and set bottom trip anchor with 15k Set down. Pull 1 OK over to verify set. Shear bolt setting down 35-45K, 3 times, and pull up to neutral position. Rotate free at 4-6K free Torque. Top of window = 4593'. Bottom = 4605'. Displace well from 8.9 PPG SFMOBM to 8.9 PPG MOBM @ 93 SPM - 330 GPM's, 2350 PSI. Mud @ YP - 19, Visc - 66. Total displacement = 183 BBLS. Mill window as per BOT rep from 4593'- 4605'(12'), and open hole from 4605'- 4632'(27'), leaving 20' of gauged hole as per plan. Avg mill speed through window = 5.50 ft/hr. Avg Weight on mills = 2-7K, with torque at 3-8K at 50-110 RPM's. 93 SPM - 330 GPM's and 2350 PSI. Obtain SPR's @ 4593 MD 3510 TVD Pump #1 = 25 SPM - 300 PSI, 35 SPM - 460 PSI. Pump #2 = 25 SPM - 310 PSI, 35 SPM - 450 PSI. PU WT = 105K, SO WT = 80K, ROT WT = 80K. Wash & ream through window area, while pump sweep to clean window. Work window with and without pump to verify good & clean. Pump sweep @ 90 SPM - 330 GPM, 2170 PSI, with 110 RPM's - 3-4K torque. Monitor well - static. Pump dry job, and blow down Top Drive. POOH with milling assembly, monitor well at BHA - static. PJSM, discuss Safety and Lay down procedure. Lay down both Bumper jars. Plug in and download MWD assembly. Printed: 12/29/2005 9:54:06 AM .vo Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-164 U-164 ROT - DRILLING nl334@ppco.com Doyon 141 11/13/2005 16:30 - 17:15 0.75 WIN 17:15 - 18:30 1,25 WIN 18:30 - 20:15 1.75 WEL 20:15 - 23:00 2.75 WEL 23:00 - 00:00 1 1.001 WEL PROD2 PROD2 BOPE I PROD2 BOPE PROD2 BOPE IPROD2 11/14/2005 Z:00-00:30 I 0.50 DRILL PULD PROD2 f :30 - 01:45 1.25 DRILL PULD PROD2 01:45 - 02:45 1 1.00 1 DRILL OTHR I PROD2 02:45 - 03:15 1 0.50 DRILL TRIP PROD2 03:15 - 05:30 1 2.251 DRILL I TRIP 1 PROD2 07: 07:00 - 07:105 I PROD2 I 0.25 DRILL RR PV PROD2 07:15 - 07:30 1 0.251 DRILL I REAM I PROD2 07:30 - 12:00 1 4.501 DRILL I DRLG I PROD2 12:00 - 00:00 1 12.001 DRILL I DRLG I PROD2 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Continue Breakout & lay down remaining BHA. Lay down 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.51'), 6.750" Upper mill (5.82'), 1 - jnt 3 1/2" HWDP (29.8'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (24.18'), TM HOC (10.90'). Upper mill gauged to full 6.750". Clean & clear rig floor. Send tools out. Pull stack washer to rig floor. RU, BOLDS & pull wear bushing. MU stack washer and flush stack. Lay do stack washer. Rig up to test BOP's. Install test plug. Fill stack & lines. Test BOP stack, HCR's & manual valves. Test Choke mainfold valves, upper & lower IBOP valves, floor safety valve & dart valve. Pull test joint &test Blind rams. All tests 250 PSI Low / 3500 PSI High. Recorded on chart. Perform Accumulator test @ 1900 PSI after close, 2minutes -36 sec. 3000 PSI -3 minutes -12 sec. John Crisp with AOGCC waived witness of test. Pull test plug, install wear bushing & RILDS. Rig down all test equipment. Blow down equipment. Clean & Clear Rig Floor area. Send tools out. Pull tools to Rig Floor. PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA #6. Make up 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor ( 32.83'), 4 3/4" Non Mag float sub ( 1.41'), 4 3/4" Integral Blade stabilizer ( 5.46'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES ( 24.18'), PWD Collar (10.73'), TM HOC ( 10.90'), 3 - 4 3/4" Non Mag Flex Drill Collars ( 92.80'), 4 7/8" Crossover sub ( 1.66'), 1 - Jnt of 4" HWDP ( 30.33'), 4 3/4" Drilling jars 94.55 Hrs on 11/11/05) ( 28.59'), 4 - Jnts 4" HWDP ( 120.96'). Total BHA length = 369.17'. Plug In and Upload MWD assembly RIH to 369' and perform shallow pulse test @ 85 SPM - 300 GPM - 2225 PSL Continue Trip In hole from 369'- 1953'( 1584'). MU 4 3/4" Andergauge 'Agitator and Shock Sub with crossovers. Agitator = 1975.55' from bit. Continue TIH to 4588'. Slip & Cut 60' of drilling line. Inspect Saver sub. Good. PU WT = 95K, SO WT = 75K. Orient toolface to High Side, pumps off, slide through window area from 4592' - 4605' with no issues to bottom of gauged hole @4623'. Pumps on @ 300 GPM's - 3450 PSI. Obtain clean hole ECD @ 9:64 PPG before begin drilling. MW = 9.0 PPG. YP = 17, Visc = 72 Wash & Ream from 4623'- 4632'( 9'). Pumps @ 86 SPM, 300 GPM's - 3450 PSI. Directional drill 6 3/4" Hole in the "B" lateral from 4632'- 4962' MD (330'). TVD = 3523'. ART = 1.18 HRS, AST = 1.64 HRS, ADT = 2.82 HRS. PU WT = 95K, SO WT = 72K, ROT WT = 83K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 5-1 OK, RPM's = 80, Pumps @ 86 SPM, 300 GPM's - 3450 PSI. Total Jar Hrs = 97.04. Total Bit Hrs = 2.82 ECD at 9.72 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 4679' MD, 3526' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 890 PSI. Pump #2 - 25 SPM - 630 PSI, 30 SPM - 870 PSI. Continue Directional drill 6 3/4" Hole in the "B" lateral from 4962'- 5581' MD (889'). TVD = 3523'. ART = 9.50 NRS, AST =.60 HRS, ADT = 10.10 HRS. PU WT = 96K, SO WT = 71 K, ROT WT = 83K, Torque off Printed: 12/29/2005 9:54:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/14/2005 112:00 - 00:00 0 U-164 U-164 ROT - DRILLING nl334@ppco.com Doyon 141 12.001 DRILL I DRLG I PROD2 11/15/2005 100:00-12:00 I 12.001 DRILL I DRLG I PROD2 12:00 - 00:00 1 12.001 DRILL I DRLG I PROD2 11/16/2005 100:00-12:00 12:00 - 00:00 12.001 DRILL 1 DRLG I PROD2 12.001 DRILL 1 DRLG 1 PROD2 • Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: btm = 4K, Torque on bottom = 4-5K. WOB = 2-12K, RPM'S = 75-80, Pumps @ 86 SPM, 300 GPM's - 3550 PSI. Total Jar Hrs = 109.96. Total Bit Hrs = 12.92 ECD at 9.81 PPG. Mud WT = 8.9 PPG Viscosity = 71, YP = 18. SPR's @ 5333' MD, 3532' TVD. Pump #1 - 25 SPM - 600 PSI, 35 SPM - 880 PSI. Pump #2 - 25 SPM - 620 PSI, 30 SPM - 910 PSI. Observed Drilling through Concretions at 5082'- 5090'(8'), 5106'- 5128' (22'), 5235'-5248' (13'), 5440'- 5445'(5'). Max Gas units = 135 Continue Directional drill 6 3/4" Hole in the "B" lateral from 5581' - 6581' MD (1000'). TVD = 3528'. ART = 7.90 HRS, AST = 2.30 HRS, ADT = 9.39 HRS. PU WT = 100K, SO WT = 69K, ROT WT = 81 K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-15K, RPM's = 75-80, Pumps @ 86 SPM, 300 GPM's - 3700 PSI. Total Jar Hrs = 119.35. Total Bit Hrs = 22.31 ECD at 10.20 PPG. Mud WT = &B PPG Viscosity = 65, YP = 18. SPR's @ 6264' MD, 3527' TVD. Pump #1 - 25 SPM - 630 PSI, 35 SPM - 810 PSI. Pump #2 - 25 SPM - 630 PSI, 30 SPM - 860 PSI. Observed Drilling through Concretions at 5581'- 5589' (8'), 5702' - 5705' (3'), 5778'-5782' (4'), 5784'- 5793' (9'), 5809'-5822- (13), 5993'-6001' (8'), 6240'-6243' (3'),6436'-6440- (4),6506-6518. (12'), 6524'-6533' (9'). Max Gas units = 131. Survey @ 6499' MD, 3525' TVD = 89.73 Deg Inc, AZ - 358 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 6581'-7655' MD (1074'). TVD = 3541'. ART = 6.85 HRS, AST = .62 HRS, ADT = 7.47 HRS. PU WT = 106K, SO WT = 64K, ROT WT = 84K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-15K, RPM's = 75-80, Pumps @ 91 SPM, 320 GPM's - 3750 PSI. Total Jar Hrs = 126.82. Total Bit Hrs = 29.13 ECD at 10.34 PPG. Mud WT = 8.8 PPG Viscosity = 66, YP = 18. SPR's @ 7480' MD, 3535' TVD. Pump #1 - 25 SPM - 630 PSI, 35 SPM - 840 PSI. Pump #2 - 25 SPM - 690 PSI, 30 SPM - 910 PSI. Observed Drilling through Concretions at 6809'- 6814'(5'), 6774'- 6784'(10'), 6983' - 6986'(3'), 7634'-7640'(6'). Max Gas units = 248. Survey @ 7526' MD, 3536' TVD = 87.86 Deg Inc, AZ - 1.91 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 7655' -8813' MD (1158'). TVD = 3575'. ART = 6.87 HRS, AST = 1.82 HRS, ADT = 8.69 HRS. PU WT = 103K, SO WT = 65K, ROT WT = 81 K, Torque off 1 btm = 5K, Torque on bottom = 5K. WOB = 2-15K, RPM's = 90, Pumps @ 91 SPM, 320 GPM's - 3900 PSI. Total Jar Hrs = 135.51. Total Bit Hrs = 37.82 ECD at 10.41 PPG. Mud WT = 8.8 PPG Viscosity = 63, YP = 18. Gels 17/25 SPR's @ 8320' MD, 3550' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 850 PSI. Pump #2 - 25 SPM - 650 PSI, 30 SPM - 860 PSI. Observed Drilling through Concretions at 7702'- 7709' (7'), 7989'- 7998' (9'), 8225' - 8232' (7'), 8236'-8260'(24'), 8476'-8492- (16), 8682'-8700' (18'), 8705'-8723' (18'), 8749'-8755' (6'). Max Gas units = 243. Survey @ 8645' MD, 3570' TVD = 87.68 Deg Inc, AZ - 357.0 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 8813' - 9880' MD (1067'). TVD = 3575'. ART = 5.60 HRS, AST = 1.94 HRS, ADT = 7.54 HRS. PU WT = 11 OK, SO WT = 60K, ROT WT = 84K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 2-15K, RPM's = 90, Pumps @ 88 SPM, 310 GPM's - 3850 PSI. Total Jar Hrs = 143.05. Total Bit Hrs = 45.20 ECD at 11.0 PPG. Mud WT = 8.85 PPG Viscosity = 62, YP = 18. Gels 17/25 SPR's @ 9722' MD, 3536' TVD. Pump #1 - 25 SPM - 650 PSI, 35 SPM - 900 PSI. Pump #2 - 25 SPM 680 PSI, 30 Printed: 12/29/2005 9:54:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-164 U-164 ROT - DRILLING n1334@ppco.com Doyon 141 11/16/2005 112:00-00:00 I 12.001 DRILL I DRLG I PROD2 11/17/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 00:00 12.00 DRILL DRLG PROD2 11/18/2005 00:00 - 01:15 01:15 - 05:30 05:30 - 06:30 06:30 - 08:00 08:00 -10:30 10:30 - 12:00 12:00 - 18:00 18:00 - 18:30 1.251 DRILL 1 CIRC 1 PROD2 4.251 DRILL I WIPR I PROD2 1.001 RIGMNTJ RGRP J PROD2 1.50{ DRILL WIPR 1PROD2 2.501 DRILL 1 CIRC 1 PROD2 1.501 DRILL !CIRC 1 PROD2 6.001 DRILL ITRIP IPROD2 0.501 DRILL (TRIP IPROD2 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: SPM - 920 PSI. Observed Drilling through Concretions at 9600'- 9606' (6). Max Gas units = 167. Survey @ 9770' MD, 3536' TVD = 91.14 Deg Inc, AZ - 358.45 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral from 9880' - 10748' MD (868'). TVD = 3591'. ART = 7.57 HRS, AST =.95 HRS, ADT = 8.52 HRS. PU WT = 118K, SO WT = 57K, ROT WT = 82K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 2-15K, RPM's = 95, Pumps @ 86 SPM, 300 GPM's - 3900 PSI. Total Jar Hrs = 151.57. Total Bit Hrs = 53.72 ECD at 10.92 PPG. Mud WT = 8.8 PPG Viscosity = 66, YP = 17. Gels 17/26 SPR's @ 10189' MD, 3557' TVD. Pump #1 - 25 SPM - 770 PSI, 35 SPM - 920 PSI. Pump #2 - 25 SPM - 710 PSI, 30 SPM - 970 PSI. Observed Drilling through Concretions at 9942'- 9956'(12% 942'- 9956'(12'), 10146'-10150' (4'),10184'-10191' (7'),10264'-10281- (17'), 10376'-10381'(5'),10395'-10460'(65'),10471'-10495 (24'). Max Gas units = 85. Survey @ 10607' MD, 3580' TVD = 85.40 Deg Inc, AZ - 359.00 Deg. Continue Directional drill 6 3/4" Hole in the "B" lateral to TD from 10748'-11472' MD (724'). TVD = 3612'. ART = 7.45 HRS, AST =.69 HRS, ADT = 8.14 HRS. PU WT = 140K, SO WT = 55K, ROT WT = 90K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 2-15K, RPM's = 95, Pumps @ 86 SPM, 300 GPM's - 4000 PSI. Total Jar Hrs = 159.71. Total Bit Hrs = 61.86 ECD at 11.34 PPG. Mud WT = 8.85 PPG Viscosity = 70, YP = 17. Gels 17/26 SPR's @ 11017' MD, 3596' TVD. Pump #1 - 25 SPM - 760 PSI, 35 SPM - 1040 PSI. Pump #2 - 25 SPM - 790 PSI, 30 SPM - 1080 PSI. Observed Drilling through Concretions at 10497' - 10503' (6'), 10513'-10525' (12% 10582'-10600' (18'), 10699'-10715' (16'), 10780'-10800' (20'), 11096-11102' (T), 11186-11188' (2'), 11297'-11303'(6'), 11326-11327' (2'), 11338--11345- (T). Max Gas units = 75. Survey @ 11472' MD, 3612' TVD = 83.37 Deg Inc, AZ - 2.88 Deg. Last survey @ TD and projected Inc and AZ. Pump 35 BBL Hi Visc weighted sweep + 2 Btms up @ 84 SPM- 300 GPM's - 4100 PSI. Reciprocate & Rotate drill dtring @ 100 RPM's, 6K Torque. PU WT = 140K, SO WT = 55K, ROT WT = 81 K. Observe 15% increase in cutting when sweep across shakers, and shakers clean. Monitor well - Static. BROOH from 11472'- 8791'( 2681'). Back ream rate at 86 SPM - 300 GPM's - 3900 PSI. Torque = 6K. 80 RPMs. PU WT = 107K, SO WT = 64K @ 8791'. Observed clean hole and no issues. Finish circulating bottoms up and shakers clean. Hole took proper fill. Observed Swivel packing leaking. Change out swivel packing. Trip back in hole on elevators from 8791'- 11472'( 2681'). Observed clean hole conditions. PU WT = 125K, SO WT = 52K. Pump 35 BBL Hi Visc weighted sweep + 2 Btms up @ 85 SPM- 300 GPM's - 4000 PSI. Reciprocate & Rotate drill dtring @ 95 RPMs, 6K Torque. PU WT = 140K, SO WT = 55K, ROT WT = 81 K. Observe 15% increase in cutting when sweep across shakers, and shakers clean. Displace well from 8.85 PPG MOBM to 8.80 PPG SFMOBM @ 81 SPM -4000 PSI. 95 RPMs, 5-6K torque. POOH on elevators form 11472'- 1975'( 9497'). Observe clean hole conditions and hole taking proper fill. Make up Top drive and pump down drill string to verify Anderguage Agitator working. Observe Agitator working with "LESS" vibration than normal or expected. Breakout and lay down Agitator & Shock Sub with Printed: 12129/2005 9:54:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/18/2005 18:00 - 18:30 18:30 - 20:15 • IJ -164 U-164 ROT - DRILLING n1334@ppco.com Doyon 141 0.501 DRILL I TRIP PROD2 1.75 DRILL PULD PROD2 23:30 - 00:00 0.50 WINDOV0PULD CMPLT2 11/19/2005 100:00-00:45 I 0.751 WINDOV(IPULD I CMPLT2 00:45 - 05:15 1 4.501 WINDOWTRIP I CMPLT2 05:30 - 06:15 1 0.75 WINDOWTRIP I CMPLT2 06:15 - 06:45 1 0.501 WINDOW RIP I CMPLT2 06:45 - 07:30 1 0.751 WINDOWCIRC I CMPLT2 07:30 -10:15 1 2.751 WINDOWTRIP (CMPLT2 10:15 -11:15 I 1.00 WINDOZULD CMPLT2 11:15 -12:00 j 0.75 WINDO�pULD CMPLT2 12:00 -12:30 1 0.501 WINDOWPULD I CMPLT2 12:30 -13:30 1 1.001 CMPLTNI FCO I CMPLT2 13:30 - 14:30 1 1.001 CMPLTNI FCO I CMPLT2 14:30 - 16:30 16:30 - 18:00 f 1.50 CMPLTN FCO I CMPLT2 • Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: crossovers. Continue POOH from 1976- 95' ( 1880'). Stand back 3 - 4 3/4" Non Mag Flex Drill Collars ( 92.80'), 4 7/8" Crossover sub ( 1.66), 1 - Jnt of 4" HWDP ( 30.33'), 4 3/4" Drilling jars ( 159.71 Hrs on 11/18/05) 28.59'), 4 - Jnts 4" HWDP ( 120.96'). Plug in and download MWD assembly. Continue POOH, breakout and lay down BHA #6. Lay down 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6R - 6.0 stage with a 1.5 degree bend in motor ( 32.83'), 4 3/4" Non Mag float sub ( 1.41'), 4 3/4" Integral Blade stabilizer ( 5.46'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES ( 24.18'), PWD Collar (10.73'), TM HOC ( 10.90'). Bit Gauged to 2 / 2 / WT / T / X / I / NO / TD. Clear & Clean Rig Floor area. Send tools outside Service Top Drive, and Lubricate rig. Inspect Swivel packing. Pull tools to rig floor for next BHA. PJSM with crew & BOT REP. Discuss safety issues, new hands on rig crew, and procedure for picking up next BHA. PJSM -New Crew, Discuss Safety issues, weather @ -34 Degrees and Procedure for PU whipstock retrieving assembly. MU BHA. MU Retrieving Hook ( 7.5'), 1 - int 3 1/2" HWDP ( 29.50'), 4 3/4" NM Float sub ( 1.41'), 2 - 4 3/4" Bumper jars ( 7.84', 7.57'), 4 3/4"Oil Jars ( 11.14'), Crossover ( 1.66'), 2 - stands Hybrid Push Pipe ( 180.94'). Trip in hole from 248' - 3051' ( 2803'), stopping on each joint to reposition and inspect, and retorque each super slider, 90 total. Fill drill string with mud, and blow down Top Drive. . Continue TIH from 3051'- 4600'( 1549'). PU WT = 102K, SO WT = 80K. Pump @ 313 GPMs - 1650 PSI. Locate & hook whipstock @ 4596' ( slot). Pull up to 50K over to jar 3 times and observe assembly pull free @ 190K, @ 4597' Circulate Bottoms up @ 313 GPM's - 1600 PSI. No Gas observed, well static. Blow down Top Drive. PU WT = 108K. POOH from 4597'- 247' (4350'), slow at first to observe well taking correct hole fill, not swabbing. Breakout & lay down Retrieving Hook assembly. Breakout & lay down whipstock and space out assembly. Crew change. Continue Breakout & lay down whipstock and space out assembly. Observe debris, sand , shale above and below Debris Barrier cup, with quite a bit of clay and sand on Space out pipe as well. Observed Debris cup folded over. Recovered a "Small Fitting" on cup. ??? Pictures sent to town. Clean & clear rig floor area. perform thorough Inspection of Top Drive. Observed no missing fittings. Pull tools to rig floor. MU clean out BHA. MU 6 3/4" HTC STR09 Roller Cone insert Bit (.80% Bit sub ( 2.02'), 4 3/4" Integral Blade Stabilizer (5.46'), 3 - NM Flex drill collars (92.80'), Crossover Sub (1.66'), 1 - 4" HWDP (30.33'),4 3/4" Drilling Jar ( 156.52 HRS on 11/18/05) ( 28.59'), and 4 -jnts 4" HWDP ( 120.96'). Total BHA = 282.62'. Trip in hole from 283' - 4575' ( 4292'). Break circulation @ 80 SPM - 1290 PSI, UP WT = 103K, SO WT = 80K, ROT WT = 84K. Wash down from 4575'- 4703'(128'). Continue rotate and wash from TOW @ 4593' back down to top of PKR at 4703'. Printed: 12/29/2005 9:54:06 AM 20:15 - 21:15 1.00 DRILL OTHR I PROD2 21:15 - 22:00 0.75 DRILL PULD PROD2 22:00 - 22:30 0.50, DRILL PULD- CMPLT2 22:30 - 23:00 0.50 RIGMNT RSRV CMPLT2 23:00 - 23:30 0.50 WINDOWPULD CMPLT2 23:30 - 00:00 0.50 WINDOV0PULD CMPLT2 11/19/2005 100:00-00:45 I 0.751 WINDOV(IPULD I CMPLT2 00:45 - 05:15 1 4.501 WINDOWTRIP I CMPLT2 05:30 - 06:15 1 0.75 WINDOWTRIP I CMPLT2 06:15 - 06:45 1 0.501 WINDOW RIP I CMPLT2 06:45 - 07:30 1 0.751 WINDOWCIRC I CMPLT2 07:30 -10:15 1 2.751 WINDOWTRIP (CMPLT2 10:15 -11:15 I 1.00 WINDOZULD CMPLT2 11:15 -12:00 j 0.75 WINDO�pULD CMPLT2 12:00 -12:30 1 0.501 WINDOWPULD I CMPLT2 12:30 -13:30 1 1.001 CMPLTNI FCO I CMPLT2 13:30 - 14:30 1 1.001 CMPLTNI FCO I CMPLT2 14:30 - 16:30 16:30 - 18:00 f 1.50 CMPLTN FCO I CMPLT2 • Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: crossovers. Continue POOH from 1976- 95' ( 1880'). Stand back 3 - 4 3/4" Non Mag Flex Drill Collars ( 92.80'), 4 7/8" Crossover sub ( 1.66), 1 - Jnt of 4" HWDP ( 30.33'), 4 3/4" Drilling jars ( 159.71 Hrs on 11/18/05) 28.59'), 4 - Jnts 4" HWDP ( 120.96'). Plug in and download MWD assembly. Continue POOH, breakout and lay down BHA #6. Lay down 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6R - 6.0 stage with a 1.5 degree bend in motor ( 32.83'), 4 3/4" Non Mag float sub ( 1.41'), 4 3/4" Integral Blade stabilizer ( 5.46'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES ( 24.18'), PWD Collar (10.73'), TM HOC ( 10.90'). Bit Gauged to 2 / 2 / WT / T / X / I / NO / TD. Clear & Clean Rig Floor area. Send tools outside Service Top Drive, and Lubricate rig. Inspect Swivel packing. Pull tools to rig floor for next BHA. PJSM with crew & BOT REP. Discuss safety issues, new hands on rig crew, and procedure for picking up next BHA. PJSM -New Crew, Discuss Safety issues, weather @ -34 Degrees and Procedure for PU whipstock retrieving assembly. MU BHA. MU Retrieving Hook ( 7.5'), 1 - int 3 1/2" HWDP ( 29.50'), 4 3/4" NM Float sub ( 1.41'), 2 - 4 3/4" Bumper jars ( 7.84', 7.57'), 4 3/4"Oil Jars ( 11.14'), Crossover ( 1.66'), 2 - stands Hybrid Push Pipe ( 180.94'). Trip in hole from 248' - 3051' ( 2803'), stopping on each joint to reposition and inspect, and retorque each super slider, 90 total. Fill drill string with mud, and blow down Top Drive. . Continue TIH from 3051'- 4600'( 1549'). PU WT = 102K, SO WT = 80K. Pump @ 313 GPMs - 1650 PSI. Locate & hook whipstock @ 4596' ( slot). Pull up to 50K over to jar 3 times and observe assembly pull free @ 190K, @ 4597' Circulate Bottoms up @ 313 GPM's - 1600 PSI. No Gas observed, well static. Blow down Top Drive. PU WT = 108K. POOH from 4597'- 247' (4350'), slow at first to observe well taking correct hole fill, not swabbing. Breakout & lay down Retrieving Hook assembly. Breakout & lay down whipstock and space out assembly. Crew change. Continue Breakout & lay down whipstock and space out assembly. Observe debris, sand , shale above and below Debris Barrier cup, with quite a bit of clay and sand on Space out pipe as well. Observed Debris cup folded over. Recovered a "Small Fitting" on cup. ??? Pictures sent to town. Clean & clear rig floor area. perform thorough Inspection of Top Drive. Observed no missing fittings. Pull tools to rig floor. MU clean out BHA. MU 6 3/4" HTC STR09 Roller Cone insert Bit (.80% Bit sub ( 2.02'), 4 3/4" Integral Blade Stabilizer (5.46'), 3 - NM Flex drill collars (92.80'), Crossover Sub (1.66'), 1 - 4" HWDP (30.33'),4 3/4" Drilling Jar ( 156.52 HRS on 11/18/05) ( 28.59'), and 4 -jnts 4" HWDP ( 120.96'). Total BHA = 282.62'. Trip in hole from 283' - 4575' ( 4292'). Break circulation @ 80 SPM - 1290 PSI, UP WT = 103K, SO WT = 80K, ROT WT = 84K. Wash down from 4575'- 4703'(128'). Continue rotate and wash from TOW @ 4593' back down to top of PKR at 4703'. Printed: 12/29/2005 9:54:06 AM • 0 Legal Well Name: IJ -164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 11/19/2005 16:30 - 18:00 1.50 CMPLTN FCO CMPLT2 Observed lots of sand across shakers at bottoms up, work drill string and circulate until shakers clean. 18:00 - 21:00 3.00 CMPLTN TRIP CMPLT2 Trip out of hole from 4703'- 383'(4420'). Breakout & lay down clean out assembly. Lay down 6 3/4" HTC STR09 Roller Cone insert Bit ( .80'), Bit sub ( 2.02'), 4 3/4" Integral Blade Stabilizer (5.46'), 3 - NM Flex drill collars (92.80'), Crossover Sub (1.66'), 1 - 4" HWDP (30.33'), 4 3/4" Drilling Jar ( 156.52 HRS on 11/18/05) ( 28.59'), and 4 -jnts 4" HWDP 120.96'). Total BHA = 282.62'. 21:00 - 23:30 2.50 RIGMNT RSRV CMPLT2 Clear & clean rig floor area. Change out Saver sub on Top Drive. 23:30 - 00:00 0.50 CMPLTN RURD CMPLT2 Pull tools to floor & RU casing running equipment. Check out all Liner running order, pups, and Hook hanger assembly in Pipe shed. 11/20/2005 00:00 - 04:15 4.25 CMPLTN RUNT CMPLT2 PJSM with new crew. Discuss safety issues and procecure for PU 4 1/2" Liner assembly. Make up Guide shoe joint with ROT Silver Bullet Guide shoe and crossover ( 31.86'). Continue RIH with 4 1/2" Blanks / Slots as per liner detail. Run a total of 109 Blanks, 109 Slots, with 2 Swell packers spaced out to locate at 9462'& 8804'. 04:15 - 04:30 0.25 CMPLTN RUNT CMPLT2 We tagged the A2 liner top Crossover, and pulled back to rotate 1/2 RH turn in string and went through window on second attempt. 04:30 - 07:00 2.50 CMPLTN RUNT CMPLT2 Continue RIH picking up 4 1/2" liner as per detail, from 4595'- 6833' (2238'). 07:00 - 08:30 1.50 CMPLTN RUNT CMPLT2 PJSM. Discuss safety issues and procedure for making up Slim Hole MWD assmy. Make up Baker Model B1 FHH Hook Hanger assembly, pups, with crossover joint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. Total Hook Hanger assembly = 55.70'. 08:30 - 12:00 3.501 CMPLT TRIP CMPLT2 Continue TIH with liner assembly on drill pipe from 6877'- 9681' (2804'). Perform pulse test on MWD assembly, good test, and fill drill string every 10 stands @ 128 GPM's -700 PSI. 12:00 - 13:00 1.00 CMPLTN TRIP CMPLT2 Continue TIH with liner on Drill pipe from 9681'- 11421'( 1740'). Fill every 10 stands. 13:00 - 15:30 2.50 CMPLTN OTHR CMPLT2 Break circulation at 125 GPM - 1100 PSI. Orient to 10 Degrees left of high side, slack off to liner depth at 11452'. Hook window. PU and orient 180 degrees out and slack off to RIH past bottom of window to liner depth of 11460'. Pull Back up, reorient to 10 degrees left of high side and land Hook Hanger on bottom of window @ 4605'. Set down 30K. Drop 1 3/4" ball and chase with 3 BPM - 1100 PSI. Slow pump to 1 BPM - observe ball land & seat, pressure to 2800 PSI. Shear off & pull up to 11 OK. Attempt to shear ball with pressure to 4200 PSI. Not sheared. Pull 1 stand, RU test pump and shear ball at 4800 PSI. Rig do test pump & blow down lines. Top of hook hanger @ 4587.37' 15:30 - 17:30 2.00 CMPLTN TRIP CMPLT2 POOH with running and setting tools. 17:30 - 18:30 1.00 CMPLTRURD CMPLT2 Breakout, lay down and inspect running and setting tools. 18:30 - 19:30 1.00 CMPLTN RURD CMPLT2 Clean & clear rig floor area. Pull tools to floor. RU casing running equipment for LEM run. 19:30.- 20:00 0.50 CMPLTSFTY CMPLT2 PJSM with entire crew, BOT rep. Discuss safety Issues and procedure for LEM make up with 2 7/8" inner string. 20:00 - 21:30 1.50 CMPLTN PULD CMPLT2 Make up LEM assembly. Baker Seal assembly (3.26'), Crossover joint IBT x STL ( 42.74'), 4 1/2" IBT pup ( 30.84'), Carrico "DB" Nipple 3.563" ID (1.52'), 4 1/2" IBT JNT (31.09'), 3 - 4 1/2" IBT pups (14.08',9.83',3.82'), LEM assembly (34.62'), 6 - JNTs of 4 1/2" IBT (182.35'), 4 1/2" IBT pup ( 5.80'), Baker Casing Swivel (2.81'), XO Bushing (1.41'), 109-47 Casing Seal Bore receptacle ( 19.65'). Set low Printed: 12/29/2005 9:54:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/20/2005 20:00 - 21:30 21:30 - 00:00 11/2112005 100:00 - 00:30 • IJ -164 IJ -164 ROT - DRILLING n1334@ppco.com Doyon 141 1.50 CMPLTN PULD CMPLT2 2.50 CMPLTN PULD CMPLT2 0.501 CMPLTNI PULD I CMPLT2 00:30 - 01:15 1 0.751 CMPLTNI PULD 1 CMPLT2 05:15 - 08:30 I 3.251 CMPLTNI PULD I CMPLT2 08:30 -11:15 1 2.751 CMPLTNI TRIP 1 CMPLT2 11:15 -12:00 I 0.751 CMPLTNI RUNT 1 CMPLT2 12:00 -12:30 1 0.501 CMPLTNI PCKR I CMPLT2 12:30 -14:15 1.751 CMPLTN TRIP CMPLT2 14:15 -16:30 2.251 CMPLTN PULD CMPLT2 16:30 - 17:00 1 0.501 CMPLTNI PULD 1 CMPLT2 17:00 -17:30 1 0.501 WINDOWPULD 1 PROD3 17:30 - 19:00 I 1.501 WINDOWPULD I PROD3 0 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: in slips for inner string. RU 2 7/8" inner string tools. MU Ball seat and XO (2.49'), on first joint. Observe joint galded when torque applied. Breakout & change out joint and inspect crossover. Good. Make up first joint. MU torque = 1500 ft/lbs. RIH with 5 joints of 2 7/8" 8.7# inner string tubing. Continue RU 2 7/8" inner string tools. MU torque = 1500 ft/lbs. RIH with 3 more joints of 2 7/8" 8.7# inner string tubing. Observe Tag up solid on inner string. Calculate that the Collars on 2 7/8" tbg were 3.68" OD. ID of LEM = 3.68", and DB nipple ID = 3.56". We tagged with the Shear Sub (3.66") on the LEM. Rig Up & POOH with 8 joints of 2 7/8" Inner String. Breakout & lay down Shear Sub assembly. Rig down 2 7/8" equipment to run inner string.Clear & clean floor area. Slip & Cut drilling line. Inspect brakes on draw works. Service Top Drive. Wait on 2 3/8" inner string pipe, and equipment form Baker Fishing shop. Load pipe shed with 2 3/8" DP. Pull handling tools to rig floor. Strap all tools and pipe. MU Mule shoe & Shear Sub assembly with 11 jnts of 2 3/8" spaced out to 13' below seals. MU ZXP packer assembly (18.90'). PU WT = 45k, SO WT = 45K. Total BHA = 420.97' TIH with LEM assembly & inner string from 421'-4685'(4264'). PU WT = 118K, SO WT = 93K. Rig up and pump down string @ 160 GPMs- 850 PSI to wash from 4685'-4748- ( 63'). wITH pumps off, seals going into CSB and observe "LAtch Up" on Hook Hanger with LEM @ 4749' as per detail. Drop 1 3/4" ball down string. Allow ball to fall chase with 2 BPM and observe ball landed. Pressure up to 3000 PSI to set ZXP packer, continue pressure to 4000 PSI to release setting tool. Pull up to 115K, bleed pressure. RU and pump down annulus to pressure test ZXP to 1000 PSI for 5 Minutes. Record on chart. Bleed all pressures and blow down lines. B Lateral Liner top @ 4345.76'. POOH with LEM Running and setting tools, from 4345'- 384'(3961'). PJSM, discuss safety issues, and procedure for laying down tools. Lay down & inspect running tool. Rig up and lay down 2 3/8" inner string with shear sub and mule shoe. Clean & clear floor area, lay down all 2 3/8 handling equipment and tools. PJSM with crew, MWD and BOT reps. Discuss Safety issues and procedure for PU Whipstock assembly and space out pipe. Pull all tools and equipment to rig floor. Make up D Lateral whipstock assembly. Make up Whipstock assembly & space out pipe. MU Seal Assembly with Stop Sub (1.92'), 4 5/8 Unloader Sub (5.18'), Kelly saver sub (2.70'), 2- jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.00'), Bottom Trip Anchor (3.22'), Safety Disconnect (2.63'), Ported Drain Sub (1.50'), Debris Barrier sub w/ Cup (1.55'), & 5/8" Whipstock slide (14.10'). 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.46'), 6.750" Upper mill (5.84'), 1- jnt 3 1/2" HWDP (29.50'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (24.18% TM HOC (10.90'), 2 - 4 3/4" Bumper jars (7.84', 7.57')Crossover IF x XT39 (1.66'), 2 stands 4 3/4" Hybrid Push pipe(180.94'). Total BHA = 381.43' Printed: 12/29/2005 9:54:06 AM 01:15 - 01:45 0.50 CMPLTN PULD CMPLT2 01:45 - 02:30 0.75 RIGMNT RSRV CMPLT2 02:30 - 03:15 0.75 RIGMNT RSRV CMPLT2 03:15 - 05:15 1 2.00 WAITON EQIP CMPLT2 05:15 - 08:30 I 3.251 CMPLTNI PULD I CMPLT2 08:30 -11:15 1 2.751 CMPLTNI TRIP 1 CMPLT2 11:15 -12:00 I 0.751 CMPLTNI RUNT 1 CMPLT2 12:00 -12:30 1 0.501 CMPLTNI PCKR I CMPLT2 12:30 -14:15 1.751 CMPLTN TRIP CMPLT2 14:15 -16:30 2.251 CMPLTN PULD CMPLT2 16:30 - 17:00 1 0.501 CMPLTNI PULD 1 CMPLT2 17:00 -17:30 1 0.501 WINDOWPULD 1 PROD3 17:30 - 19:00 I 1.501 WINDOWPULD I PROD3 0 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: in slips for inner string. RU 2 7/8" inner string tools. MU Ball seat and XO (2.49'), on first joint. Observe joint galded when torque applied. Breakout & change out joint and inspect crossover. Good. Make up first joint. MU torque = 1500 ft/lbs. RIH with 5 joints of 2 7/8" 8.7# inner string tubing. Continue RU 2 7/8" inner string tools. MU torque = 1500 ft/lbs. RIH with 3 more joints of 2 7/8" 8.7# inner string tubing. Observe Tag up solid on inner string. Calculate that the Collars on 2 7/8" tbg were 3.68" OD. ID of LEM = 3.68", and DB nipple ID = 3.56". We tagged with the Shear Sub (3.66") on the LEM. Rig Up & POOH with 8 joints of 2 7/8" Inner String. Breakout & lay down Shear Sub assembly. Rig down 2 7/8" equipment to run inner string.Clear & clean floor area. Slip & Cut drilling line. Inspect brakes on draw works. Service Top Drive. Wait on 2 3/8" inner string pipe, and equipment form Baker Fishing shop. Load pipe shed with 2 3/8" DP. Pull handling tools to rig floor. Strap all tools and pipe. MU Mule shoe & Shear Sub assembly with 11 jnts of 2 3/8" spaced out to 13' below seals. MU ZXP packer assembly (18.90'). PU WT = 45k, SO WT = 45K. Total BHA = 420.97' TIH with LEM assembly & inner string from 421'-4685'(4264'). PU WT = 118K, SO WT = 93K. Rig up and pump down string @ 160 GPMs- 850 PSI to wash from 4685'-4748- ( 63'). wITH pumps off, seals going into CSB and observe "LAtch Up" on Hook Hanger with LEM @ 4749' as per detail. Drop 1 3/4" ball down string. Allow ball to fall chase with 2 BPM and observe ball landed. Pressure up to 3000 PSI to set ZXP packer, continue pressure to 4000 PSI to release setting tool. Pull up to 115K, bleed pressure. RU and pump down annulus to pressure test ZXP to 1000 PSI for 5 Minutes. Record on chart. Bleed all pressures and blow down lines. B Lateral Liner top @ 4345.76'. POOH with LEM Running and setting tools, from 4345'- 384'(3961'). PJSM, discuss safety issues, and procedure for laying down tools. Lay down & inspect running tool. Rig up and lay down 2 3/8" inner string with shear sub and mule shoe. Clean & clear floor area, lay down all 2 3/8 handling equipment and tools. PJSM with crew, MWD and BOT reps. Discuss Safety issues and procedure for PU Whipstock assembly and space out pipe. Pull all tools and equipment to rig floor. Make up D Lateral whipstock assembly. Make up Whipstock assembly & space out pipe. MU Seal Assembly with Stop Sub (1.92'), 4 5/8 Unloader Sub (5.18'), Kelly saver sub (2.70'), 2- jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.00'), Bottom Trip Anchor (3.22'), Safety Disconnect (2.63'), Ported Drain Sub (1.50'), Debris Barrier sub w/ Cup (1.55'), & 5/8" Whipstock slide (14.10'). 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.46'), 6.750" Upper mill (5.84'), 1- jnt 3 1/2" HWDP (29.50'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (24.18% TM HOC (10.90'), 2 - 4 3/4" Bumper jars (7.84', 7.57')Crossover IF x XT39 (1.66'), 2 stands 4 3/4" Hybrid Push pipe(180.94'). Total BHA = 381.43' Printed: 12/29/2005 9:54:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: • 1 J-164 IJ -164 ROT - DRILLING n1334@ppco.com Doyon 141 (11/21/2005 19:45 - 20:45 0.00 WINDOWR PR PROD3 20:45 - 00:00 1 3.251 WINDOWTRIP I PROD3 111/22/2005 �00:00-01:15 1.251 WINDOVTRIP PROD3 01:15 - 01:45 0.50 WINDO RIP PROD3 01:45 - 02:15 0.50 WINDO ETW PROD3 02:15 - 03:00 1 0.75 WINDO IRC PROD3 03:00 - 09:00 6.00 WINDO TWP i PROD3 9:45 0,75�VVINDOVVCIRC 109:45-103:30 3.75 WINDO�RIP �PROD3 13:30 - 14:00 0.501 VVINDOVYOTHR � PROD3 14:00 - 16:00 2.00 WINDOTHR JPROID3 16:00 -19:15 1 3.251 DRILL PULD I PROD3 19:15 - 21:00 1.75 DRILL ITRIP IPROD3 21:00 - 21:30 1 0.50 DRILL IREAM 1PROD3 21:30 - 00:00 1 2.501 DRILL I DRLH 1 PROD3 111/23/2005 100:00-12:001 12.001 DRILL 1 DRLH I PROD3 12:00 - 21:00 21:00 - 21:30 21:30 - 00:00 11124/2005 00:00 - 01:30 01:30 - 05:30 9.001 DRILL 1 DRLH 1 PROD3 • Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Plug in and up load MWD assembly Pick up last stand of push pipe and perform shallow pulse test @ 300 Gpms - 1000 PSI. TIH with whipstock assembly and space out pipe at 2 minutes / stand as per BOT rep. from 381' - 3548' (3167'). Fill drill string @ 2250'. Wash & MADD Pass K-13 f/ 3,361' to 3,542'. Continue to RIH to 4,212'. Orient Whipstock to 11 deg. left of highside, Set same @ 4,248', Up wt. 11 OK, Dn 87K. Change over to 8.8 ppg MOBM at rate of 298 gpm @ 2200 psi. Mill 6-3/4" window f/ 4,248' to 4,260', Continue to mill to 4,294' with 6-3/4" gauged hole to 4,284'. Pump Hi -vis weighted sweep & Circ hole clean at rate of 302 gpm @ 2000 psi, 60 RPM, Up 105K, Dn 93K, Rot 97K POOH, Lay down Jars & Bumper sub, Down load MWD tool, Lay.down & gauge mill- OK. Lay down tools from floor, Clean floor. Pull wear bushing, Flush out stack, Function all rams, Reflush stack, Rig down , Set wear bushing. PJSM, Pick up 6-3/4" HTC, HCM 505Z Bit, 5200 series GeoPilot, Load MWD tools, Shallow test tools. RIH to 4,196', Fill pipe & Check MWD @ 2,700'. Break circ, Work thru window @ 4,248' to 4,260'- No Problem, RIH to 4,284', Ream out of gauge hole to 4,294'. Drill 6-3/4" hole w/ GeoPilot f/ 4,294' to 4,476' MD 3,479' TVD (182'), ADT= 1.83 hrs, WOB 10/20K, 95 RPM, 265 gpm @ 1700 psi, Up 100K, Dn 78K, Rot 90K, TQ on 4500 ft/lb, TQ off 4000 ft/lb, PWD Clean hole ECD= 9.8 ppg, PWD ECD 9.97 ppg, Max Gas 68 units, Drilled concretion f/ 4,302' to 4,310'. Drill 6-3/4" hole w/ GeoPilot f/ 4,476' to 5,555' MD 3,462' TVD (1,079'), ADT= 8.32 hrs, WOB 10/20K, 120 RPM, 302 gpm @ 2200 psi, Up 98K, Dn 76K, Rot 86K, TQ on 4000 ft/lb, TQ off 4000 ft/lb, Ave. ECD's 9.9 ppg, Max Gas 125 units, Drilled concretions f/ 4933' to 4955', 5037' to 5051', 5084' to 5097', 5156' to 5176', 5433' to 5447', 5453' to 5456'. Drill 6-3/4" hole w/ GeoPilot f/ 5,555' to 5,947' MD 3,465' TVD (392'), ADT= 3.79 hrs, WOB 8/25K, 80/130 RPM, 310 gpm @ 2300 psi, Up 100K, Dn 75K, Rot 86K, TQ on 5000 ft/lb, TQ off 4000 ft/lb, Ave. ECD's 10.1 ppg, Max Gas 110 units, Drilled concretions f/ 5542' to 5560', 5626' to 5628', 5674' to 5682', 5697' to 5700', 5832' to 5835'. 0.50 DRILL DEQT PROD3 After drilling on asumed concretion for 4 hours, Lost 200 psi pump pressure, Sent command to GeoPilot and regained 200 psi then lost 200 psi again, Picked up off btm and lost 350 psi, Tagged btm and gained 500 psi, Perp to POOH. 2.50 DRILL TRIP PROD3 POOH on elevators, No problems- Hole in good shape. 1.50 DRILL TRIP PROD3 POOH (GeoPilot & Bit Twisted off), Down load MWD, Lay down Tools, Clean rig floor. Note; Fish in hole= Bit, Bit sub stab, GeoPilot (Total 15.80'), TOF @ 5931'. 4.00 WELCT BOPE PROD3 Rig & test BOP to 250 psi low & 3500 psi High, Choke & kill valves and maniflod, Top & Blind rams Hydrill & floor valves. Note; Unable to contact AOGCC, Left messages with Slope pager & Anchorage number, Also sent e-mail. Printed: 12/29/2005 9:54:06 AM I pL 4 LL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: • 1 J-164 U-164 ROT - DRILLING n1334@ppco.com Doyon 141 11/24/2005 05:30 - 06:30 j 1.00 FISH PULD 06:30 - 09:15 2.75 FISH TRIP 09:15 - 09:30 0.25 FISH FISH 11112512005 11/26/2005 09:30 -14:30 1 5.001 FISH ITRIP 14:30 -15:00 0.50 FISH PULD 15:00 -17:15 2.25 FISH TRIP 17:15 - 17:45 0.50 FISH FISH 17:45 - 21:30 3.75 FISH TRIP 21:30 - 23:00 1.50 FISH PULD 23:00 - 00:00 1.00 DRILL PULD 00:00 - 00:15 0.25 DRILL PULD 00:15 - 01:15 1.00 DRILL PULD 01:15 - 01:45 0.50 DRILL PULD 01:45 - 02:00 0.25 DRILL DEQT 02:00 - 05:00 3.00 DRILL TRIP 05:00 - 05:15 0.25 DRILL REAM 05:15 - 08:15 3.00 DRILL DRLH 08:15 - 09:00 1 0.751 DRILL I OTHR 09:00 - 12:00 I 3.001 DRILL I TRIP 12:00 -12:45 1 0.751 DRILL I OTHR 12:45 - 15:00 2.25 FISH I PULD 15:00 - 17:45 2.75 FSH TRIP 17:45 - 18:00 1 0.25 � FISH I FISH 18:00 - 21:30 3.50 FISH TRIP 21:30 - 22:30 1.00 FISH PULD 22:30 - 00:00 1.50 DRILL PULD 00:00 - 00:45 0.75 DRILL PULD 00:45 - 02:15 1.50 DRILL PULD 02:15 - 03:15 1.00 DRILL PULD 03:15 - 04:00 0.75 DRILL PULD 04:00 - 04:15 0.25 DRILL DEQT 04:15 - 07:15 3.00 DRILL TRIP 07:15 - 08:45 1.50 DRILL SURV 08:45 - 09:15 1 0.501 DRILL (TRIP 0 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: PRODS Make up Baker fishing tools 6-114" Overshot w/ 5-1/4" grapple. PROD3 RIH w/ fishing tools to 5901'. PROD3 Break circ w/ 2.5 bpm @ 300 psi, 25 rpm w/ 3K TO, Work over fish & had 200 psi pump increase, 6K TO, Set Dn w/ 20K, Pick up off bttm w/ 5 to 1 OK drag off bttm. PROD3 Monitor well, POOH to 4221', Monitor well, POOH- No fish recovery, Break out and inspect grapple (Showed scaring and signs that fish was inside overshot), Clean rig floor. PROD3 Make up Baker fishing tools 6-1/4" Overshot w/ 5-1/8" grapple. PROD3 RIH w/ fishing tools to 5901'. PROD3 Break circ w/ 2.5 bpm @ 320 psi, Up 98K, Dn 75K, 30 rpm wl 4K TO, Work over fish @ 5931' & had no pump increase, Set Dn w/ 30K & Stalled top drive, Pick up off bttm w/ 115K & Broke back to 105K, Set back down w/ 30K. - -- PROD3 POOH w/ fish- No problems. PROD3 Lay down fish and fishing tools, Clear & clean rig floor. PROD3 Make up BHA #13, 6-3/4" Bit & GeoPilot. PROD3 Continue to make up BHA #13. PROD3 Program MWD Tools. PROD3 Continue to make up BHA #13. PROD3 Pulse test MWD tools, Break in GeoPilot bearings, 300 gpm @ 1550 psi, Stage rpm f/ 5 to 55. PROD3 RIH with no problems to 5,876', Filled pipe @ 2702'& 5036'. PROD3 Precautionary wash & ream to bttm @ 5,947'. PROD3 Drill 6-3/4" hole w/ GeoPilot f/ 5,947' to 6,155' MD 3,458' TVD (208'), ADT= 1.83 hrs, WOB 5/7K, 120 RPM, 313 gpm @ 2600 psi, Up 105K, Dn 65K, Rot 85K, TO on 5000 ft/lb, TO off 4000 ft/lb, Ave. ECD's 10.1 ppg, Max Gas 99 units. PROD3 At 6,155' Down linked to GeoPilot and observed 1500 psi pressure loss in pump pressure, Checked surface equipment- OK, Prep to POOH, Monitor well, Blow down top drive. PROD3 POOH looking for wash out- Found Drilling Jars had parted at lower body section - (Total fish in hole= 220.66', TOF @ 5934'), Lay down upper jar section. PROD3 Clear & Clean rig floor. PROD3 Pick up & Make up 6-3/8" Over shot, Jars & Bumper sub, 1 std HWDP. PROD3 RIH with no problems to 5939', Up 95K, Dn 68K, 30 rpm w/ 3500 ft/Ib TO. PROD3 Engage fish f/ 5,939' to 5,945', 2.5 bpm @ 350 psi, 30 rpm, Set down 18K, Gained 7K extra wt. PROD3 POOH w/ fish, Had 25K drag @ 5,685'. PROD3 Lay down remainder of broken Jars, Lay down fishing tools. PROD3 Lay down 4-HWDP, X -O, 3-NMDC's, Float sub, Stab. PROD3 Finish laying down BHA #13. PROD3 Pick up & Make all new BHA #15, MWD tools, Stabs, PWD, Float sub, X/O sub. PROD3 Program MWD tools. PROD3 Pick up 3 new NMDC's, 4- HWDP, Jars, 1-HWDP. PROD3 Shallow test MWD tools, Blow down top drive. PROD3 RIH to 5,940' with no problems, Filled pipe @ 270'& 5035'. PROD3 Take check shot surveys every 30'f/ 5940' to 6153'- Found 22.18 deg. dogleg @ 5933'. PROD3 POOH to 5,460'& Resurvey for open hole side track. Printed: 12/29/2005 9:54:06 AM • Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 111/26/2005 109:15 - 11:30 1 2.251 DRILL I DRLH I PROD3 11:30 -18:30 1 7.001 DRILL 1 DRLH I PROD3 18:30 - 00:00 I 5.50) DRILL I DRLH 1 PROD3 111/27/2005 100:00-12:00 1 12.001 DRILL 1 DRLH 1 PROD3 12:00 - 00:00 1 12.001 DRILL I DRLH I PROD3 111/28/2005 100:00 - 02:30 02:30 - 03:45 03:45 - 08:45 2.501 DRILL I DRLH I PROD3 1.25 l DRILL I DEQT 1 PROD3 5.001 DRILL ITRIP IPROD3 08:45 - 09:30 0.75 DRILL ITRIP JPROD3 09:30 -10:15 0.75 DRILL PULD JPROD3 10:15 -10:45 0.50 DRILL OTHR PROD3 10:45 - 12:00 1.25 DRILL I PULD I PROD3 12:00 -13:45 13:45 -15:00 15:00 -16:15 16:15 -18:30 18:30 - 20:00 20:00 - 00:00 11/29/2005 100:00 - 06:30 1.751 DRILL I PULD I PROD3 1.25 DRILL TRIP PROD3 1.25 RIGMNT RSRV PROD3 2.25 DRILL TRIP PROD3 1.50 DRILL REAM PROD3 4.00 DRILL DRLH PROD3 6.501 DRILL I DRLG 1 PROD3 0 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Trough w/ GeoPilot f/ 5,460' to 5,470' in order to sidetrack well, Up 102K, Dn 72K, Rot 84K, 300 gpm @ 2250 psi, 120 rpm, 5000 ft/lb TO. Drill 6-3/4" hole w/ GeoPilot f/ 5,470' to 6,155' MD 3,473' TVD (685'), ADT= 5.44 hrs, WOB 8/17K, 100 RPM, 284 gpm @ 2300 psi, Up 105K, Dn 73K, Rot 86K, TO on 5000 ft/lb, TO off 4000 ft/lb. Drill 6-3/4" hole w/ GeoPilot f/ 6,155' to 6,560' MD 3,467' TVD (405'), ADT= 3.67 hrs, WOB 8/15K, 120 RPM, 313 gpm @ 2500 psi, Up 112K, Dn 69K, Rot 85K, TO on 5500 ft/Ib, TO off 5000 ft/lb, Ave. ECD's 10.1 ppg, Max Gas 83 units. Drill 6-3/4" hole w/ GeoPilot f/ 6,560' to 7,577' MD 3,486' TVD (1,017'), ADT= 8.58 hrs, WOB 3/15K, 115 RPM, 305 gpm @ 2550 psi, Up 112K, Dn 69K, Rot 86K, TO on 5500 ft/lb, TO off 5000 ftllb, Ave. ECD's 10.1 ppg, Max Gas 99 units, 6533' to 6573', 6584' to 6609', 7264' to 7267', 7278' to 7282', 7326' to 7332', 7366' to 7374', 7442' to 7444', 7467' to 7479'. Drill 6-3/4" hole w/ GeoPilot f/ 7,577' to 8,512' MD 3,506' TVD (935'), ADT= 9.41 hrs, WOB 5/18K, 100/120 RPM, 316 gpm @ 2800 psi, Up 125K, Dn 62K, Rot 85K, TO on 7000 ft/lb, TO off 6000 ft/lb, Ave. ECD's 10.4 ppg, Max Gas 99 units, 7594' to 7603', 7683' to 7685', 7745' to 7747', 7791' to 7794', 7826' to 7830', 7908' to 7915', 7955' to 7964', 8122' to 8131', 8137' to 8150', 8160' to 8171', 8180' to 8188', 8195' to 8200', 8430' to 8435'. Drill 6-3/4" hole w/ GeoPilot f/ 8,512' to 8,620' MD 3,504' TVD (108'), ADT= 2.73 hrs, WOB 7/14K, 90 RPM, 270 gpm @ 2200 psi, Up 122K, Dn 66K, Rot 83K, TO on 7000 ft/lb, TO off 6000 ft/lb, Ave. ECD's 10.1 ppg, Max Gas 99 units. GeoPilot failure- Circ & Attempt to reestablish communication with GeoPilot. POOH to 7650' (No swabbing - Good fill), Observe well, Pump Dry job, POOH to BHA & Stand back same. Down load MWD Lay down hangoff collar, PWD, MWD, Stab, GeoPilot, Bit. Clear and clean rig floor. Pick up Bit, GeoPilot, Pony collar, DM collar, Smart stab, SlimPhase 4 w/DGR, PWD, Hangoff collar. Program MWD tools, RIH w/ NMDC's, HWDP, Jars, Surface test MWD tools. RIH to 4192'. Slip & cut drilling line, Service top drive and drawworks. RIH with no problems to 8211' (Pipe stopped -Ran out of weight). Wash & ream f/ 8211' to 8620'. Drill 6-3/4" hole w/ GeoPilot f/ 8,620' to 8,955' MD 3,494' TVD (335'), ADT= 2.41 hrs, WOB 8/12K, 120 RPM, 330 gpm @ 3200 psi, Up 134K, Dn OK, Rot 85K, TO on 6000 ft/lb, TO off 5000 ft/lb, Ave. ECD's 11.0 ppg, Max Gas 57 units. No Concretions. Continue Directional drill 6 3/4" Hole in the "D" lateral from 8955'-9474' MD (519'). TVD = 3479'. ADT = 5.34 HRS. PU WT = 130K, SO WT = 60K, ROT WT = 85K, Torque off btm = 5K, Torque on bottom = 5.5K. WOB = 5-20K, RPM's = 120, Pumps @ 92 SPM, 327 GPM's - 3100 PSI. Total Jar Hrs = 37.58 Total Bit Hrs = 7.75 ECD at 10.94 PPG. Mud WT = 8.8 PPG Viscosity = 79, YP = 17. Gels 15/22. Max Gas units = 79. Survey @ 9388' MD, 3475.3' TVD = 88.56 Deg Inc, AZ - 7.78 Deg. Observed drilling through concretions @ 9259'- 9262'(3'), Printed: 12/29/2005 9:54:06 AM • • Legal Well Name: U-164 Common Well Name: U-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 11/29/2005 00:00 - 06:30 6.50 DRILL DRLG PROD3 06:30 - 08:15 1.75 DRILL OTHR PROD3 08:15 - 12:00 3.75 DRILL TRIP PROD3 12:00 - 13:00 1.00 DRILL TRIP PROD3 I 13:00 - 14:15 1.25 DRILL PULD PROD3 14:15 - 16:30 2.25 DRILL PULD PROD3 16:30 - 21:00 4.50 DRILL TRIP PROD3 21:00 - 21:15 0.25 DRILL REAM PROD3 21:15 - 22:00 0.75 DRILL REAM PROD3 22:00 - 00:00 2.00 DRILL DRLG PROD3 11/30/2005 00:00 - 12:00 12.00 DRILL DRLG PROD3 9279'-9290'(1 V), 9430'-9434' (4'), 9464'-9474' (10') = 28' total concretions. Observed MWD failure. Attempted to restart MWD, cycle pumps multiple times, adding 20K to WOB as per DD pulling from 9474'- 9239'. No success achieved. Monitor well - static. Pump dry job. POOH from 9239'- 4196'(5043'). Monitor well at window depth. Static. Continue POOH from 4196'- 368'(3828'). Calculated hole fill at 50 BBLs, Actual hole fill @ 56 BBLS. Rack back 4" HWDP & Jars, NM Flex Drill collars. Lay down Stabilizer & Float sub. Plug in and download MWD assembly. Lay down TM, PWD, Slimphase 4 w/ DGR & EWR, Smart Stabilizer, DM Pony Collar Geo Pilot and Bit. PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA #17. Make up 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80) TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor ( 32.75'), 4 3/4" Non Mag float sub (2.34'), 4 3/4" Integral Blade stabilizer (4.58'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES ( 24.38'), PWD Collar (10.78'), TM HOC ( 10.90'), 3 - 4 3/4" Non Mag Flex Drill Collars ( 92.80'), 4 7/8" Crossover sub ( 1.07'), 1 - Jnt of 4" HWDP ( 30.33'), 4 3/4" Drilling jars 37.58 Hrs on 11/29/05) ( 28.88'), 4 - Jnts 4" HWDP ( 121.2l').Total BHA length = 369.34'. Perform Shallow pulse test @ 84 SPM - 1900 PSI. Good Test. Trip in hole from 369'- 8727'(8358'). Run 17 stands of 4" DP(1587.96'), Install Crossover sub (1.64'), Andergauge Agitator (8.73'), Shock Sub (8.37'), and Crossover Sub (1.66').Fill drill string every 20 stands. Continue TIH to 8727'. PU WT = 92K, SO WT = 80K, Orient and observe no issues going through window area. Wash & Ream from 8727'- 8793'(66'), @ 40 SPM, 142 GPM's - 1500 PSI, 70 RPM's Torque @ 6K. Observe correct hole fill. Continue RIH to 9354' on elevators. Wash & Ream from 9354'- 9474'(120'). Continue Directional drill 6 3/4" Hole in the "D" lateral from 9474'- 9496- MD (18'). TVD = 3478'. ADT = .85 HRS. AST = .38 HRS. ART = .47 HRS. PU WT = 11 OK, SO WT = 47K, ROT WT = 77K, Torque off btm = 5K, Torque on bottom = 6K. WOB = 5-12K, RPM's = 75, Pumps @ 81 SPM, 287 GPM's - 3800 PSI. Total Jar Hrs = 38.43 Total Bit Hrs = .85 ECD at 10.39 PPG. Mud WT = 8.85 PPG Viscosity = 88, YP = 18. Gels 16124. Max Gas units = 30, BGG = 17 units. Survey @ 9388' MD, 3475.3' TVD = 88.56 Deg Inc, AZ - 7.78 Deg. Observed drilling through concretions @ 9474'- 9480' (6) = 6' total concretions. SPR's @ 9537' MD, 3481' TVD. Pump #1 - 25 SPM - 740 PSI, 35 SPM - 1060 PSI. Pump #2 - 25 SPM - 840 PSI, 30 SPM - 1190 PSI. Continue Directional drill 6 3/4" Hole in the "D" lateral from 9496-10070' MD (574'). TVD = 3501'. ADT = 7.84 HRS. AST = 1.48 HRS. ART = 6.36 HRS. PU WT = 110K, SO WT = 50K, ROT WT = 79K, Torque off btm = 5K, Torque on bottom = 6K. WOB = 3-15K, RPM's = 75, Pumps @ 82 SPM, 291 GPM's 3800 PSI. Total Jar Hrs = 46.27 Total Bit Hrs = 8.69 ECD at 10.83 PPG. Mud WT = 8.85 PPG Viscosity = 80, YP = 18. Gels 15/24. Max Gas units = 65, BGG = 15 units. Survey @ 9957' MD, 3497.41' TVD = 87.6 Deg Inc, AZ - 357.82 Deg. Observed drilling through concretions @ 9492'- 9505' (13'), Printed: 12/29/2005 9:54:06 AM Legal Well Name: U-164 Common Well Name: U-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 11/30/2005 00:00 - 12:00 12.00 DRILL DRLG PROD3 12:00 - 00:00 12.00 DRILL DRLG PROD3 12/1/2005 00:00 - 05:30 5.50 DRILL DRLG PROD3 05:30 - 07:30 2.00 DRILL CIRC PROD3 07:30 - 09:15 1.75 DRILL WIPR PROD3 09:15 - 09:30 0.25 DRILL WIPR PROD3 09:30 - 10:30 1.00 DRILL WIPR PROD3 1'0:30 - 12:00 1.50 DRILL WIPR PROD3 12:00 -18:15 6.25 DRILL WIPR PROD3 18:15 -19:00 0.75 DRILL CIRC PROD3 19:00 - 20:30 1.50 DRILL WIPR PROD3 120:30 - 21:45 1.25 DRILL WIPR PROD3 9574'-9580'(6'), 9585'-9591' (6), 9600'-9604'(4'), 9610'-9620'(10.), 9628'-9632' (4'), 9640'-9675' (35'),9714'-9721- (T) = 85' total concretions. SPR's @ 10005' MD, 3504' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 920 PSI. Pump #2 - 25 SPM - 640 PSI, 30 SPM - 910 PSI. Continue Directional drill 6 314" Hole in the "D" lateral from 10070'- 11047- MD (977'). TVD = 3541'. ADT = 7.02 HRS. AST = 5.92 HRS. ART = 1.10 HRS. PU WT = 122K, SO WT = 50K, ROT WT = 81 K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 3-10K, RPM's = 80, Pumps @ 81 SPM, 287 GPM's - 3975 PSI. Total Jar Hrs = 53.29 Total Bit Hrs = 15.71 ECD at 11.06 PPG. Mud WT = 8.90 PPG Viscosity = 80, YP = 17. Gels 15/22. Max Gas units = 94, BGG = 11 units. Survey @ 10974' MD, 3537.11' TVD = 87.22 Deg Inc, AZ - 357.39 Deg. Observed drilling through no concretions this tour. SPR's @ 10929' MD, 3532' TVD. Pump #1 - 25 SPM - 820 PSI, 35 SPM - 1160 PSI. Pump #2 - 25 SPM - 810 PSI, 30 SPM - 1140 PSI. Pump 35 BBL Hi Visc weighted sweep, observed 25% increase in cuttings on shakers when sweep returned. Continue Directional drill 6 3/4" Hole in the "D" lateral from 11047'- 11524- MD (477'). TVD = 3561'. ADT = 3.35 HRS. AST =.29 HRS. ART = 3.06 HRS. PU WT = 132K, SO WT = 45K, ROT WT = 92K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 4-6K, RPM's = 85, Pumps @ 80 SPM, 284 GPM's - 4100 PSI. Total Jar Hrs = 56.64 Total Bit Hrs = 19.37 ECD at 11.23 PPG. Mud WT = 8.80 PPG Viscosity = 81, YP = 18. Gels 16/24. Max Gas units = 87. Survey @ 11524' MD, 3561.5' TVD = 89.03 Deg Inc, AZ - 358.56 Deg. Observed drilling through concretions @ 11509'-1 1514' (5'). SPR's @ 10929' MD, 3532' TVD. Pump #1 - 20 SPM - 750 PSI, 30 SPM - 950 PSI. Pump #2 - 20 SPM - 740 PSI, 30 SPM - 940 PSI. Pump 35 BBL Hi Visc weighted sweep, observed 25% increase in cuttings on shakers when sweep returned. Pump a 35 BBL Hi Visc sweep @ 80 SPM - 284 GPM's - 4100 PSI. Observed 20% increase in cuttings on shakers. Monitor well - static. POOH on elevators from 11524'- 10102'(1422'). PU WT = 150K, SO WT = 60K. Flow check - static. Pump dry job, blow down Top Drive & Lines. Continue POOH from 10102' - 8980' (1122'). Pulled into cutings bed. RU & BROOH from 8980'- 8793'(187'), @ 281 GPM - 3500 PSI, 90 RPM's - 6K torque. Continue BROOH from 8793'- 8682'(101'), observing hole packing off. Work string to clean up hole and continue BROOH from 8682'- 4404'( 4278') with no issues. Back ream @ 85 SPM - 302 GPM - 3825 PSI. 90 RPM's with 5K torque. Pull on elevators from 4404'- 4218' observing no issues through window area. Pump a 35 BBL Hi Visc weighted sweep + 3 Bottoms up @ 93 SPM - 330 GPM's - 3500 PSI. Observed 10% increase in cuttings on shakers. PU WT = 91K, SO WT = 81K. Orient and TIH through window with no issues, and continue TIH on elevators to tag up at 6150' DPM. Obtain survey and verify we had traveled into OLD hole. Survey indicated oriented at 35 degrees left of high side, POOH from 6150' - 5430' (720'). Orient to low side at 168 degrees right and RIH slowly to bit depth of 5602' to obtain and compare surveys to Printed: 12129/2005 9:54:06 AM • Legal Well Name: 1J-164 DRILL Common Well Name: 1J-164 17:30 -19:45 Event Name: ROT - DRILLING PULD Contractor Name: n1334@ppco.com 0.75 Rig Name: Doyon 141 CMPLT3 �a�'1bX 151 Qat T e'a 1.75 jI[trc RIP 12/1/2005 20:30 - 21:45 1.25 DRILL WIPR PROD3 21:45 - 00:00 2.25 DRILL WIPR PROD3 12/2/2005 00:00 - 03:00 3.00 DRILL WIPR PROD3 03:00 - 05:45 I 2.75 I DRILL I CIRC 1 PROD3 05:45 - 07:00 1 1.251 DRILL I CIRC I PROD3 07:00 - 07:30 1 0.501 DRILL 1 OBSV 1 PROD3 07:30 - 12:00 1 4.501 DRILL ]TRIP 1 PROD3 112:00 -15:00 1 3.001 DRILL -LTRIP 1 PROD3 15:00 -17:00 1 2.001 DRILL I PULD I PROD3 17:00 - 17:30 0.50 DRILL PULD CMPLT3 17:30 -19:45 2.25 DRILL PULD CMPLT3 19:45 - 20:30 0.75 WINDOWPULD CMPLT3 20:30 - 22:15 1.75 WINDO RIP CMPLT3 22:15 - 22:45 0.50 WINDO THR CMPLT3 22:45 - 23:15 0.50 WINDO IRC CMPLT3 I 23:15 - 00:00 0.75 W INDOV TRIP CMPLT3 12/3/2005 100:00 - 02:30 1 2.501 WINDOWTRIP I CMPLT3 02:30 - 03:45 1 1.251 WINDOWPULD 1 CMPLT3 • Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: verify traveling into new hole back to 6150'. Continue TIH on elevators from 6150'- 9890'(3740'). Wash & Ream from 9890'- 11524'(1634') @ 90 RPM's,6K torque, 270 GPM - 4100 PSI. Pump 35 BBL Hi Visc weighted sweep + 2 Bottoms up @ 275 GPM's - 4100 PSI. Observed 10% increase in cuttings at shakers when sweep returned. Displace well with 8.9 PPG SFMOBM @ 275 GPM's - 4100 PSI. ECD = 11.64 PPG. Obtain SPR's. #2 pump - 20 SPM - 910 PSI, 30SPM - 1210 PSI. Monitor well - static. Drop 1 7/8" drift in drill pipe. POOH on elevators from 11524'- 5710'(5814'). Observe no swabbing and hole taking correct hole fill. Continue POOH on elevators from 5710' - 369' (5341'). Observe no swabbing and hole taking correct hole fill. Stop @ top of window, monitor well - static. Breakout & lay down BHA #17. Lay down after plug in and download MWD assembly, 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80) TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor ( 32.75'), 4 3/4" Non Mag float sub (2.34'), 4 3/4" Integral Blade stabilizer (4.58'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES ( 24.38'), PWD Collar (10.78'), TM HOC 10.90'), Rack back 3 - 4 3/4" Non Mag Flex Drill Collars ( 92.80'), 4 7/8" Crossover sub ( 1.07'), 1 - Jnt of 4" HWDP ( 30.33'), 4 3/4" Drilling jars 37.58 Hrs on 11/29/05) ( 28.88'), 4 - Jnts 4" HWDP ( 121.21').Total BHA length = 369.34'. Gauge Bit to 1 / 1 / CT / G / X / I / NO / TD Clean & clear rig floor area. Send tools outside. Pick up 9 stands of Push Pipe from pipe shed. (2 -4 3/4" DC's and 1 - 4" DP). Pick up 1 more stand of 4" HWDP, for upcoming 4 1/2" liner run. Rack back all stands in derrick. PJSM with crew & BOT rep. Discuss safety and Procedure for picking up BHA. Make up Whipstock retrieving BHA as per BOT rep. MU Hook (7.50'), 4 3/4" Bumper jar (7.30), 4 3/4" Oil Jar (11.25'), 4 3/4" Float sub (2.34'), 2 - stands of 4" HWDP (181.56'), and crossover (1.04'). Total BHA = 210.99' TIH with retrieving assembly, fill drill string every 25 stands. Obtain parametrs @ 4178'. PU WT = 125K, SO WT = 104K. Locate & hook window slot by working drill string and putting 1/8 turns in DP to hook. Pull up to 200K to fire jars, repeat 2 times, and pull to 250K to observe assembly free and moving up hole with 7K increase in upweight. Observe well swabbing. Circulate Bottoms up @ 248 GPM's - 1300 PSI. Observe 27 BSL loss of fluid as we CBU. Monitor well - static. POOH slow @ 10 ft/minute observe swabbing for 3 stands and then hole taking fluid. Slowly increase string speed as we wore out cup on the assembly. Observe hole taking proper fill after 3 full stands pulled. Continue POOH with whipstock retrievinig assembly from 3906'- 210' (3696'). Breakout & lay down Whipstock retrieving assembly. Layed down Hook (7.50'), 4 3/4" Bumper jar (7.30), 4 3/4" Oil Jar (11.25'), 4 3/4" Float sub (2.34'), 2 - stands of 4" HWDP (181.56'), and crossover (1,04'). Total BHA = 210.99'. Continue POOH lay down whipstock and space out assembly. Layed down Seal Assembly with Stop Sub ( 1.92'), 4 5/8" Printed: 12/29/2005 9:54:06 AM Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 12/3/2005 02:30 - 03:45 1.25 WINDO ULD CMPLT3 03:45 - 04:15 0.50 WINDO ULD CMPLT3 04:15 - 05:15 1.00 CMPLTN RURD CMPLT3 05:15 - 09:30 4.25 CMPLTN RUNT CMPLT3 09:30 - 09:45 0.25 CMPLTNI RUNT CMPLT3 09:45 -10:15 0.50 CMPLT RUNT CMPLT3 10:15 -10:45 0.50 CMPLTN RUNT CMPLT3 10:45 -12:00 1.25 CMPLTN RUNT CMPLT3 i 12:00 - 13:00 1.00 CMPLTN RUNT CMPLT3 13:00 -14:15 1.25 CMPLTN RUNT CMPLT3 14:15 -16:30 2.25 CMPLTN TRIP CMPLT3 16:30 - 18:00 1.50 CMPLTN OTHR CMPLT3 18:00 -18:15 0.25 CMPLTN OTHR CMPLT3 18:15 -19:00 0.75 CMPLTN CIRC CMPLT3 19:00 - 21:00 2.00 CMPLTN TRIP CMPLT3 21:00 - 22:00 1.00 CMPLTN PULD CMPLT3 22:00 - 23:15 1.25 RIGMNT RSRV CMPLT3 23:15 - 00:00 0.75 CMPLTN RURD CMPLT3 12/4/2005 00:00 - 00:45 0.75 CMPLTN RUNT CMPLT3 Unloader Sub ( 5.20'), 2 - 3 112 IF pups (11.85', 4.75'), 2- jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.08'),Bottom Trip Anchor (3.22'), Safety Disconnect (2.70'), Ported Drain Sub (1.02'), Debris Barrier sub w/ Cup (1.69'), & 5/8" Whipstock slide (15.47'). Clear & Clean rig floor area, send tools outside. Rig up casing equipment, power tongs, slips, elevators etc... Hold PJSM with crew and BOT rep. Discuss safety issues and procedure for picking up 4 1/2 slotted liner assembly. Pick up Baker 3 1/2" Guide shoe & bent joint with crossover. Continue RIH with 130 joints 4 1/2" L80 IBT 12.6# slotted / blank liner as per detail. PU Swell packers spaced out @ 9158'& 8637'. Install 150, 6 1/8" x 4 1/2" HydroForm Centralizers & stop rings on each joint except constrictor joints, all as per running detail. Constrictors space out to depths of, 10858', 10608'-, 10008', 9758', 8078', 7828', 7238', 6988', 6398', 6148', 5558', 5308', 4718', and 4418'. Total of 14 constrictors. Pull 2 718" tools and handling equipment to floor. Continue RIH with Liner assembly. Ran by window with bent joint to tag lower liner XO @ 4384' (Took 2 attempts to get thru window). Pull assembly back to above window top, orient to slack off and RIH to observe going into open hole. Continue RIH with 176 joints total liner from 4248'- 5522'(1274'). PU WT = 80K, SO WT = 64K. Crew Change. PJSM. (Note; 4 joints prior to side track @ 5460' turned pipe 1-1/2 turns to the right to turn bent joint to 180 deg.) Continue RIH with liner from 5522'- 7225' (1703'). 231 joints total ran. Make up 3 1/8" Slimhole MWD assembly with BOT shear sub assembly, on inner string of Hook Hanger. Orient MWD to high side of Hook. Make up Hook Hanger assembly. Perform shallow pulse test @ 117 GPM - 650 PSI. PU WT = 86K, SO WT = 63K. Trip in hole with drill string, and push pipe as calculated for weight, from 7268' - 11417' (4149'). Observe no issues getting liner down in open hole. PU WT = 175K, SO WT = 65K. Orient with MWD assembly to 11 degrees left of high side @ 124 GPM - 1100 PSI, slack off to hook window @ 4263' (3' deep). Pull up 40', and orient'to low side, slack off to pass bottom of window to 4276'. Pull up 40', re -orient to window @ 11 deg left, slack off to observe hooking window. Set down 30k to verify set. Repeat. Shoe depth @ 11502'. Final survey @ 2 Degrees left of high side. RU & drop a 29/32" ball, pumping down @ 124 GPM - 1100 PSI, slowing pumps until observed ball on seat. Pressure to 4200 PSI. Pull up 90' to 11412'& verify release. Bleed pressure. PU WT = 125K, SO WT = 50K Circulate bottoms up @ 124 GPM - 1100 PSI. Monitor well - static. POOH with BOT setting and releasing tool. Observed correct hole fill @ 36 BBIs. Breakout, inspect and lay down running and setting tools. Breakout & lay down MWD assembly & shear sub assembly. All tools looked good. Slip & cut 220' of drilling line. Service top drive. Rig up casing equipment for 4 1/2" LEM run. PJSM, Discuss & verify running order of tools. PU Seal Assembly with bent joint & first joint of tubing. Crew Change. Continue RIH with LEM Assembly. Run 4 1/2" Baker Seal Assembly (3.26'), 4 1/2" Bent Joint STL x IBT (31.04'), 1-Jnt 4 1/2" IBT (31.02'), 4 Printed: 12/29/2005 9:54:06 AM Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 12/4/2005 00:00 - 00:45 0.75 CMPLTN RUNT CMPLT3 00:45 - 03:30 2.75 CMPLTN TRIP CMPLT3 03:30 - 04:00 0.50 CMPLTN PCKR CMPLT3 04:00 - 04:30 0.50 CMPLTN PCKR CMPLT3 04:30 - 07:00 2.50 CMPLT TRIP CMPLT3 07:00 - 07:45 0.75 CMPLT TRIP CMPLT3 07:45 - 12:00 4.25 CMPLT TRIP CMPLT3 12:00 -19:30 7.50 CMPLTN TRIP CMPLT3 19:30 - 19:45 0.25 CMPLTN RURD CMPLT3 19:45 - 20:15 0.50 CMPLT RURD CMPLT3 20:15 - 00:00 3.75 CMPLTN RUNT CMPLT3 12/5/2005 00:00 - 00:30 0.50 CMPLTRUNT CMPLTN 00:30 - 01:00 0.50 CMPLT ISOHO CMPLTN 01:00 - 03:00 2.00 CMPLTN SEQT CMPLTN 03:00 - 04:30 1.50 CMPLTN NUND CMPLTN 04:30 - 09:00 4.50 CMPLTN NUND CMPLTN 1/2" IBT pup (7.85'), 1-Jnt 4 12/" IBT (31.0'), LEM below Hook Hanger (24:52'), LEM above Hook Hanger (10.61'), 4 1/2" IBT pup (3.83'), 4 1/2" Casing Swivel (2.74'), 4 1/2" IBT pup (2.02'), XO Bushing 5 1/2" Hydril x 4 1/2" IBT (1.41'), 190-47 Casing Seal Bore Receptacle ( 19.68'), 7 5/8" x 5 1/2" ZXP Liner top Packer ( 18.90'), Install shear sub assembly, and MU Baker Hydraulic & Setting tools, with crossover sub (17.26'). Make Up Torque = 3500 Ft / Lbs Trip in hole with LEM assembly from 205' - 4375' (4170'). Work seals past Hook Hanger & bottom of window, observing seals going into liner top and Latching up on Hook Hanger@ 4246' as planned. Pull 10K over to verify Latch up. UP WT = 124K, SO WT = 105k. Seals spaced out to land @ 4375.01, inside Seal bore 10.35'. Drop 1 3/4 Ball and chase with 350 stks @ 3 BPM - 600 PSI to observe ball seated. Pressure up to 2500 PSI to allowZXP to set, continue pressure up to 4000 PSI to neutralize and release. Bleed pressure. Rig up and fill lines. Test down annulus 1000 PSI for 10 minutes, on chart to ensure packer integrity. Bleed pressure. Monitor well - static.Pull up and & retag top of ZXP to verify depth @ 4187' as planned. POOH from 4187'- 40'(4147'). Breakout & lay down & inspect Running & Setting tool assembly. All tools looked good. Clear & clean rig floor area, send tools outside. Rig up to lay down drill string. PJSM with crew. Discuss safety issues and plan for laying down drill string. Lay down entire drill string from derrick removing all Super Sliders, allowing for them to drain as per Target Zero. Crew Change. Continue Lay down entire drill string from derrick removing all Super Sliders, allowing for them to drain as per Target Zero. 90 Total. Rig up. BOLDS and pull wear bushing. Clean & clear rig floor area. Rig up equipment to run 4 1/2" completion string. Verify all tools in order in pipe shed. PJSM with crew. Discuss Safety issues, and procedure to run 4 1/2" completion string. MU Baker 4 3/4" SBE Seal assembly and continue RIH with 4 1/2" L80 12.6# IBT Tubing to 3960'. Install Baker 4 1/2" CMU Sliding Sleeve (OPEN) spaced out to 4137.87', 2 - Cameo GLM's with Dummy BK -5 Latch space out to 3902.53, 2336.46', and a Cameo DB -6 Nipple with 3.875" NO-GO profile spaced out at 475.13'. Make up Torque = 3500 Ft / Lbs NOTE: SIMOPS - Change out mud pump liners from 5 1/2" to 6", & cleaning pits. Continue Run 4 1/2" Completion string to 4225.71'. Make up torque = 3500 Ft/ Lbs. Tag XO @ 4225.83' with mule shoe and Pull up to install space out pups, to locate mule shoe @ 4221.83' as planned. PU WT = 74K, SO WT = 70K. Make up Vetco Gray 11" x 4 1/2" tubing hanger with 2 -way check installed. Mu Landing joint, RIH to locate and land hanger. RKB = 22.53'. Run in all lock down screws. Test upper and lower Hanger seals to 5000 PSI. 10 minutes each test. PJSM with crew. Discuss safety and cold weather issues. Discuss procedure for ND / NU. Nipple down BOP stack and all lines. Nipple up Vetco Gray Tree and actuator valve. Test Void to 5000 PSI - Printed: 17/29/2005 9:54:06 AM Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT - DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: 12/5!2005 04:30 - 09:00 4.50 CMPLTN NUND CMPLTN 09:00 - 10:00 1.00 CMPLTN FRZP CMPLTN 10:00 - 12:00 2.00 CMPLTN OTHR CMPLTN 12:00 - 14:00 2.00 CMPLTN OTHR CMPLTN 10 minutes. Test tree to 250 PSI low, 5000 PSI high - 10 minutes. Pull 2 -way check. Note: SIMOPS - RU scaffolding in cellar & RU Little Red for freeze protection services. PJSM with crew and Little Red reps. Discuss safety issues and spill prevention. Displace well with 190 BBLS of freeze protect diesel @ 5 BPM - 800 PSI. Rig Up Lubricator & set BPV. Repeat with no success. RU & put Steam on tree. NOTE : SIMOPS - Suck out cellar box with Super Sucker truck. Continue attempt to set BPV. Set BPV. Rig down lubricator Simops - Rig Down pipe shed skate, remove & clean all pits. Shut down all Glycol heaters. Blow down all steam, glycol, and H2O lines. Rig Released @ 1400 HRS - Printed: 12/292005 9:54:06 AM Halliburton Sperry -Sun Western North Slope ConocoPhillips Kuparuk IJ Pad IJ -164 Job No. AK -ZZ -0004025932, Surveyed. 10 November, 2005 Survey Report 28 December, 2005 Your Ref. API 500292327800 • Surface Coordinates: 5945730.87 N, 558693.02 E (70° 15'44.4085" N, 149° 31'31.8702" R9 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 945730.87 N, 58693.02 E (Grid) Surface Coordinates relative to Structure: 188.01 S, 98.41 W (True) Kelly Bushing Elevation: 109.00ft above Mean Sea Level Kelly Bushing Elevation: 109.00ft above Project V Reference Kelly Bushing Elevation: 109.00ft above Structure 61 w 0 "s Survey Ref.• svy2228 A Halfiburawa Company Halliburton Sperry -Sun Survey Report for Kuparuk 1J Pad -1J--164 Your Ref.• API 500292327800 Job No. AK -ZZ -0004025932, Surveyed. 10 November, 2005 Western North Slope Measured True Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (.11001t) 0.00 0.000 0.000 -109.00 0.00 0.00 N 0.00 E 5945730.87 N 558693.02 E 28.00 0.000 0.000 -81.00 28.00 0.00 N 0.00 E 5945730.87 N 558693.02 E 0.000 50.00 0.290 132.160 -59.00 50.00 0.04S 0.04 E 5945730.83 N 558693.06 E 1.318 100.00 0.310 150.040 -9.00 100.00 0.24S 0.20 E 5945730.63 N 558693.22 E 0.191 200.00 0.100 276.480 91.00 200.00 0.46S 0.25 E 5945730.41 N 558693.27 E 0.378 300.00 0.370 254.250 191.00 300.00 0.54S 0.15W 5945730.33 N 558692.88 E 0.280 352.00 0.510 245.760 243.00 352.00 0.68S 0.52 W 5945730.18 N 558692.51 E 0.296 443.00 0.460 337.170 333.99 442.99 0.51S 1.03 W 5945730.35 N 558691.99 E 0.764 533.00 1.600 8.070 423.98 532.98 1.07 N 0.99 W 5945731.93 N 558692.02 E 1.365 640.13 2.640 10.450 531.03 640.03 4.97 N 0.34 W 5945735.84 N 558692.64 E 0.974 744.88 6.450 22.180 635.44 744.44 12.80 N 2.32 E 5945743.68 N 558695.24 E 3.725 838.55 10.870 11.350 728.02 837.02 26.33 N 6.05 E 5945757.25 N 558698.86 E 5.009 927.90 12.550 11.590 815.51 924.51 44.11 N 9.66 E 5945775.05 N 558702.33 E 1.881 1020.54 14.940 7.730 905.49 1014.49 65.80 N 13.29 E 5945796.77 N 558705.79 E 2.762 1121.38 17.280 0.400 1002.38 1111.38 93.67 N 15.14 E 5945824.65 N 558707.43 E 3.070 1210.82 18.420 0.990 1087.51 1196.51 121.08 N 15.48 E 5945852.07 N 558707.55 E 1.291 1306.89 22.060 2.320 1177.63 1286.63 154.29 N 16.47 E 5945885.29 N 558708.29 E 3.819 1397.88 26.520 1.640 1260.55 1369.55 191.69 N 17.74 E 5945922.69 N 558709.27 E 4.911 1491.02 25.830 356.000 1344.15 1453.15 232.72 N 16.92 E 5945963.72 N 558708.13 E 2.771 1584.19 23.880 353.790 1428.69 1537.69 271.72 N 13.47 E 5946002.69 N 558704.37 E 2.318 1677.09 24.900 343.930 1513.33 1622.33 309.23 N 6.02 E 5946040.13 N 558696.63 E 4.513 1769.49 27.790 331.440 1596.19 1705.19 346.87 N 9.68 W 5946077.66 N 558680.64 E 6.749 1861.97 29.190 319.220 1677.54 1786.54 382.92 N 34.74 W 5946113.51 N 558655.30 E 6.472 1956.28 28.360 315.760 1760.21 1869.21 416.38 N 65.39 W 5946146.73 N 558624.38 E 1.973 2048.55 27.210 311.320 1841.84 1950.84 446.02 N 96.53 W 5946176.12 N 558593.02 E 2.565 2142.16 27.880 311.610 1924.84 2033.84 474.68 N 128.97 W 5946204.53 N 558560.36 E 0.730 2235.65 26.900 311.760 2007.85 2116.85 503.28 N 161.09 W 5946232.88 N 558528.02 E 1.051 2289.33 25.720 314.500 2055.97 2164.97 519.54 N 178.45 W 5946249.00 N 558510.52 E 3.154 2362.87 26.200 318.010 2122.10 2231.10 542.79 N 200.70 W 5946272.08 N 558488.10 E 2.189 2462.33 25.920 317.420 2211.44 2320.44 575.11 N 230.09 W 5946304.17 N 558458.45 E 0.384 2557.16 25.920 317.900 2296.73 2405.73 605.75 N 258.01 W 5946334.59 N 558430.29 E 0.221 2650.53 27.590 318.430 2380.11 2489.11 637.07 N 286.04 W 5946365.69 N 558402.02 E 1.807 2742.36 31.690 319.930 2459.90 2568.90 671.46 N 315.69 W 5946399.85 N 558372.10 E 4.537 2837.56 33.660 320.500 2540.03 2649.03 710.95 N 348.57 W 5946439.09 N 558338.91 E 2.094 2930.27 35.460 325.660 2616.40 2725.40 753.00 N 380.10 W 5946480.88 N 558307.07 E 3.705 ConocoPhillips Vertical Section Comment 0.00 CB -SS -Gyro 0.00 -0.04 -0.24 -0.46 -0.54 -0.68 -0.51 1.07 MWD+IIFR+MS+SAG 4.97 12.80 26.33 44.11 65.80 93.67 121.08 154.29 191.69 232.72 271.72 309.23 346.87 382.92 416.38 446.02 474.68 503.28 519.54 542.79 575.11 605.75 637.07 671.46 710.95 753.00 • • 28 December, 2005 - 15:25 Page 2 of 6 Dr111Quest 3.03.06.008 Halliburton Sperry -Sun Survey Report for Kuparuk 1J Pad - 1J-164 Your Ref.• API 500292327800 Job No. AK -ZZ -0004025932, Surveyed: 10 November, 2005 Western North Slope Measured True Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) plOOft) 3022.34 37.320 330.440 2690.52 2799.52 799.34 N 408.94 W 5946527.00 N 558277.86 E 3.682 799.34 3115.43 38.750 336.120 2763.87 2872.87 850.54 N 434.66 W 5946578.00 N 558251.74 E 4.060 850.54 3208.81 41.870 341.330 2835.09 2944.09 906.82 N 456.48 W 5946634.10 N 558229.48 E 4.916 906.82 3301.78 45.100 346.370 2902.55 3011.55 968.25 N 474.18 W 5946695.39 N 558211.30 E 5.096 968.25 3396.70 48.730 349.590 2967.39 3076.39 1036.03 N 488.56 W 5946763.06 N 558196.40 E 4.556 1036.03 3488.02 52.510 351.730 3025.32 3134.32 1105.67 N 499.97 W 5946832.61 N 558184.44 E 4.518 1105.67 3581.04 57.050 352.890 3078.95 3187.95 1180.96 N 510.12 W 5946907.82 N 558173.71 E 4.986 1180.96 3674.20 59.390 353.380 3128.02 3237.02 1259.58 N 519.58 W 5946986.36 N 558163.64 E 2.551 1259.58 3769.05 63.550 354.610 3173.31 3282.31 1342.44 N 528.28 W 5947069.15 N 558154.29 E 4.531 1342.44 3862.87 67.490 355.110 3212.18 3321.18 1427.46 N 535.92 W 5947154.11 N 558145.99 E 4.227 1427.46 3954.04 72.000 357.040 3243.74 3352.74 1512.77 N 541.75 W 5947239.37 N 558139.49 E 5.330 1512.77 4047.89 71.990 355.600 3272.75 3381.75 1601.84 N 547.48 W 5947328.39 N 558133.07 E 1.459 1601.84 4137.47 72.210 354.790 3300.28 3409.28 1686.78 N 554.62 W 5947413.27 N 558125.27 E 0.895 1686.78 4238.22 72.750 357.510 3330.61 3439.61 1782.63 N 561.07 W 5947509.07 N 558118.07 E 2.630 1782.63 4329.00 75.570 359.180 3355.39 3464.39 1869.91 N 563.58 W 5947596.33 N 558114.88 E 3.575 1869.91 4424.82 80.560 359.220 3375.20 3484.20 1963.62 N 564.89 W 5947690.03 N 558112.84 E 5.208 1963.62 4515.90 81.090 358.690 3389.72 3498.72 2053.52 N 566.53 W 5947779.91 N 558110.50 E 0.818 2053.52 4610.55 79.900 0.500 3405.35 3514.35 2146.86 N 567.19 W 5947873.25 N 558109.11 E 2.267 2146.86 4703.54 76.940 0.300 3424.02 3533.02 2237.95 N 566.56 W 5947964.33 N 558109.04 E 3.190 2237.95 4797.10 77.790 359.380 3444.48 3553.48 2329.24 N 566.81 W 5948055.62 N 558108.07 E 1.321 2329.24 4890.85 78.400 359.210 3463.82 3572.82 2420.97 N 567.94 W 5948147.34 N 558106.23 E 0.674 2420.97 4983.57 78.780 358.740 3482.17 3591.17 2511.84 N 569.57 W 5948238.19 N 558103.89 E 0.644 2511.84 5077.08 79.550 359.540 3499.75 3608.75 2603.67 N 570.94 W 5948330.01 N 558101.80 E 1.176 2603.67 5170.46 79.960 2.210 3516.36 3625.36 2695.54 N 569.54 W 5948421.89 N 558102.49 E 2.848 2695.54 5263.88 80.250 2.100 3532.41 3641.41 2787.51 N 566.08 W 5948513.88 N 558105.23 E 0.331 2787.51 5317.53 80.880 1.500 3541.20 3650.20 2840.40 N 564.42 W 5948566.79 N 558106.48 E 1.611 2840.40 5462.58 82.660 4.140 3561.97 3670.97 2983.77 N 557.35 W 5948710.20 N 558112.43 E 2.180 2983.77 5555.98 81.500 3.340 3574.84 3683.84 3076.08 N 551.31 W 5948802.56 N 558117.75 E 1.504 3076.08 5649.39 85.910 3.020 3585.08 3694.08 3168.76 N 546.17 W 5948895.27 N 558122.17 E 4.733 3168.76 5742.11 89.490 2.370 3588.80 3697.80 3261.29 N 541.81 W 5948987.83 N 558125.81 E 3.924 3261.29 5836.01 92.820 2.540 3586.91 3695.91 3355.07 N 537.79 W 5949081.64 N 558129.10 E 3.551 3355.07 5929.25 92.300 0.540 3582.74 3691.74 3448.18 N 535.29 W 5949174.77 N 558130.87 E 2.214 3448.18 6024.41 91.930 356.610 3579.23 3688.23 3543.22 N 537.65 W 5949269.79 N 558127.77 E 4.145 3543.22 6116.84 94.110 354.810 3574.36 3683.36 3635.26 N 544.55 W 5949361.77 N 558120.15 E 3.057 3635.26 6210.12 93.410 355.590 3568.24 3677.24 3728.01 N 552.34 W 5949454.46 N 558111.64 E 1.122 3728.01 ConocoPhillips Comment • • 28 December, 2005 - 15:25 Page 3 of 6 DrillQuest 3.03.06.008 Halliburton Sperry -Sun Survey Report for Kuparuk 1J Pad -1J--164 Your Ref.• API 500292327800 Job No. AK -ZZ -0004025932, Surveyed. 10 November, 2005 Western North Slope Measured 87.990 True Sub -Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) 512.13 W 5950592.38 N (ft) (ft) (ft) (ft) (ft) (ft) 6303.66 91.550 355.830 3564.20 3673.20 3821.19 N 559.33 W 5949547.59 N 558103.92 E 6397.86 90.080 359.660 3562.86 3671.86 3915.29 N 563.04 W 5949641.65 N 558099.48 E 6490.00 91.390 1.000 3561.67 3670.67 4007.42 N 562.51 W 5949733.78 N 558099.29 E 6583.45 89.890 1.840 3560.63 3669.63 4100.83 N 560.19 W 5949827.21 N 558100.88 E 6676.59 89.160 3.310 3561.40 3670.40 4193.87 N 556.01 W 5949920.28 N 558104.34 E 6769.69 88.970 5.290 3562.92 3671.92 4286.69 N 549.03 W 5950013.15 N 558110.60 E 6866.17 87.800 3.720 3565.64 3674.64 4382.83 N 541.45 W 5950109.35 N 558117.42 E 6962.78 89.290 6.080 3568.09 3677.09 4479.05 N 533.20 W 5950205.62 N 558124.92 E 7059.62 86.920 5.300 3571.30 3680.30 4575.35 N 523.61 W 5950302.00 N 558133.77 E 7155.03 87.430 3.210 3576.00 3685.00 4670.37 N 516.54 W 5950397.08 N 558140.09 E Dogleg Rate pi00ft) 2.005 4.355 2.034 1.840 1.762 2.136 2.029 2.888 2.576 2.252 ConocoPhillips Vertical Section Comment 3821.19 3915.29 4007.42 4100.83 4193.87 4286.69 4382.83 4479.05 4575.35 4670.37 7252.33 87.990 1.220 3579.89 3688.89 4767.52 N 512.78 W 5950494.25 N 558143.09 E 2.123 4767.52 7350.51 88.730 359.540 3582.70 3691.70 4865.65 N 512.13 W 5950592.38 N 558142.98 E 1.869 4865.65 7446.52 87.920 358.950 3585.50 3694.50 4961.61 N 513.39 W 5950688.33 N 558140.97 E 1.044 4961.61 7541.59 86.870 356.780 3589.82 3698.82 5056.51 N 516.93 W 5950783.20 N 558136.69 E 2.534 5056.51 7639.48 90.910 357.460 3591.72 3700.72 5154.24 N 521.85 W 5950880.88 N 558131.01 E 4.185 5154.24 7736.50 92.440 356.130 3588.88 3697.88 5251.06 N 527.27 W 5950977.66 N 558124.84 E 2.089 5251.06 7832.76 91.070 355.750 3585.94 3694.94 5347.03 N 534.08 W 5951073.57 N 558117.28 E 1.477 5347.03 7929.88 92.190 355.850 3583.17 3692.17 5443.85 N 541.19 W 5951170.33 N 558109.41 E 1.158 5443.85 8025.56 91.560 356.340 3580.04 3689.04 5539.25 N 547.70 W 5951265.69 N 558102.16 E 0.834 5539.25 8120.92 91.820 357.990 3577.23 3686.23 5634.45 N 552.42 W 5951360.85 N 558096.70 E 1.751 5634.45 8220.77 86.660 359.290 3578.56 3687.56 5734.23 N 554.79 W 5951460.60 N 558093.55 E 5.329 5734.23 8314.17 88.930 1.790 3582.15 3691.15 5827.54 N 553.91 W 5951553.92 N 558093.71 E 3.614 5827.54 8414.03 89.530 2.730 3583.49 3692.49 5927.32 N 549.97 W 5951653.72 N 558096.87 E 1.117 5927.32 8510.60 88.350 1.880 3585.28 3694.28 6023.79 N 546.09 W 5951750.22 N 558100.00 E 1.506 6023.79 8609.85 89.660 4.080 3587.00 3696.00 6122.88 N 540.93 W 5951849.35 N 558104.38 E 2.580 6122.88 8704.86 83.990 1.020 3592.26 3701.26 6217.60 N 536.70 W 5951944.10 N 558107.87 E 6.778 6217.60 8801.36 87.200 359.640 3599.67 3708.67 6313.80 N 536.15 W 5952040.30 N 558107.67 E 3.619 6313.80 8897.85 89.540 356.510 3602.42 3711.42 6410.18 N 539.39 W 5952136.65 N 558103.68 E 4.049 6410.18 8994.42 91.580 355.210 3601.48 3710.48 6506.48 N 546.36 W 5952232.90 N 558095.96 E 2.505 6506.48 9091.15 94.670 356.630 3596.20 3705.20 6602.81 N 553.23 W 5952329.17 N 558088.34 E 3.515 6602.81 9188.30 94.340 355.980 3588.57 3697.57 6699.46 N 559.48 W 5952425.76 N 558081.34 E 0.749 6699.46 9284.68 94.160 358.530 3581.43 3690.43 6795.45 N 564.08 W 5952521.72 N 558075.99 E 2.645 6795.45 9382.15 90.990 1.040 3577.05 3686.05 6892.81 N 564.44 W 5952619.07 N 558074.87 E 4.147 6892.81 9478.38 90.580 4.140 3575.73 3684.73 6988.92 N 560.09 W 5952715.21 N 558078.47 E 3.249 6988.92 9574.89 92.630 2.940 3573.03 3682.03 7085.20 N 554.14 W 5952811.53 N 558083.67 E 2.461 7085.20 • is 28 December, 2005 - 15:25 Page 4 of 6 DHI/Quest 3.03.06.008 Halliburton Sperry -Sun Survey Report for Kuparuk 1.1 Pad -1J-164 Your Ref.• API 500292327800 Job No. AK -ZZ -0004025932, Surveyed: 10 November, 2005 Western North Slope Measured 566.82 W True Sub -Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) 558041.20 E - 0.000 8905.74 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) 9671.41 92.180 3.040 3568.98 3677.98 7181.50 N 549.11 W 5952907.87 N 558087.95 E 0.478 9765.94 93.180 2.160 3564.56 3673.56 7275.83 N 544.82 W 5953002.23 N 558091.50 E 1.408 9864.16 92.370 0.340 3559.80 3668.80 7373.90 N 542.68 W 5953100.32 N 558092.88 E 2.026 9960.48 88.270 0.400 3559.26 3668.26 7470.20 N 542.06 W 5953196.62 N 558092.75 E 4.257 10070.01 87.240 359.050 3563.55 3672.55 7579.64 N 542.59 W 5953306.05 N 558091.37 E 1.550 10154.63 85.190 358.990 3569.14 3678.14 7664.06 N 544.03 W 5953390.46 N 558089.27 E 2.424 10250.04 82.960 359.040 3578.99 3687.99 7758.94 N 545.66 W 5953485.32 N 558086.90 E 2.338 10347.74 84.340 359.760 3589.79 3698.79 7856.03 N 546.68 W 5953582.40 N 558085.12 E 1.591 10444.44 87.510 357.370 3596.67 3705.67 7952.44 N 549.10 W 5953678.79 N 558081.95 E 4.102 10541.20 90.350 1.000 3598.47 3707.47 8049.14 N 550.47 W 5953775.48 N 558079.83 E 4.762 10640.04 91.390 1.590 3596.97 3705.97 8147.95 N 548.24 W 5953874.30 N 558081.29 E 1.210 10727.82 86.540 358.890 3598.56 3707.56 8235.68 N 547.87 W 5953962.03 N 558080.97 E 6.323 10815.96 85.570 357.010 3604.62 3713.62 8323.55 N 551.01 W 5954049.87 N 558077.15 E 2.396 10911.53 88.680 356.330 3609.41 3718.41 8418.82 N 556.56 W 5954145.10 N 558070.86 E 3.331 11002.26 88.290 356.940 3611.81 3720.81 8509.36 N 561.88 W 5954235.60 N 558064.83 E 0.798 ConocoPhillips Vertical Section Comment 7181.50 7275.83 7373.90 7470.20 7579.64 7664.06 7758.94 7856.03 7952.44 8049.14 8147.95 8235.68 8323.55 8418.82 8509.36 11093.02 86.800 356.820 3615.70 3724.70 8599.90 N 566.82 W 5954326.09 N 558059.19 E 1.647 8599.90 11184.00 85.070 357.350 3622.15 3731.15 8690.53 N 571.43 W 5954416.69 N 558053.87 E 1.988 8690.53 11274.50 86.630 355.440 3628.70 3737.70 8780.61 N 577.11 W 5954506.72 N 558047.49 E 2.721 8780.61 11364.14 86.380 358.750 3634.17 3743.17 8869.96 N 581.64 W 5954596.02 N 558042.26 E 3.696 8869.96 - 11400.00 86.380 358.750 3636.43 3745.43 8905.74 N 582.42 W 5954631.80 N 558041.20 E - 0.000 8905.74 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11400.00ft., The Bottom Hole Displacement is 8924.76ft., in the Direction of 356.258° (True). Projected Survey • 1] 28 December, 2005 - 15.25 Page 5 of 6 Dril/Quest 3.03.06.008 Halliburton Sperry -Sun Survey Report for Kuparuk 1J Pad -1J--164 Your Ref.• API 500292327800 Job No. AK -ZZ -0004025932, Surveyed. 10 November, 2005 Western North Slope Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11400.00 3745.43 8905.74 N 582.42 W Projected Survey Survey tool program for 1J-164 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 533.00 532.98 To Measured Vertical Depth Depth (ft) (ft) 533.00 532.98 11400.00 3745.43 Survey Tool Description CB -SS -Gyro MWD+IIFR+MS+SAG ConocoPhillips • • 28 December, 2005 - 15:25 Page 6 of 6 DrillQuest 3.03.06.008 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-164 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie -on Survey: 0.00' MD • 10 -Jan -06 Window / Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,400.00' 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 Il I'j 1 0(,D Signe 14 — Please call me at 273-3545 if you have any qu tions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 3604 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11/18/05 2C-05 11072930 INJECTION PROFILE 11/02/05 1 2Z-09 11057062 INJECTION PROFILE 11/03/05 1 2D-09 11141218 LEAK DETECTION LOG 11/04/05 1 3F-03 11141219 INJECTION PROFILE 11/05/05 1 3F-01 11057064 PRODUCTION PROFILE 11/05/05 1 3F-15 11057065 INJECTION PROFILE 11/07/05 1 1F -03A 11141222 LEAK DETECTION LOG 11/08/05 1 1G-17 11141221 PRODUCTION PROFILE 11/07/05 1 1J-164 N/A USIT — 11/12/05 1 3G -25X 11141229 S13HP SURVEY 11/16/05 1 1Q -20A 11144038 SBHP SURVEY 11/17/05 1 ;` SIGNED: I DATE: ►1�a� �� J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • RE: FW: USIT bond log 11-12-05 1J-164 -----Original Message ----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, November 15, 2005 8:41 AM To: Greener, Mike R. Subject: Re: FW: USIT bond log 11-12-05 11-164 Hi Mike, I agree with your TOC. Bond doesn't look bad at all. What is the plan for 1J-164, et al now?? When is it planned to put the well in service?? Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 11/14/2005 12:37 PM: Here is the cement bond log for the I J- 164. The surface shoe is at 21,332' md. The Wellsite geologist called the top of the hydrocarbons at 4,200'. I call the top of the cement on the log at +/- 3,450'. What do you think? -----Original Message ----- From: Doyon 141 Company Man Sent: Saturday, November 12, 2005 1:09 AM To: Greener, Mike R.; 'm.greeraer@att.net' Subject: USIT bond log 11-12-05 13-164 «USI Cement 015.PDS>> Mike Thornton / Scott Heim Doyon 141 Company Man Office; 907-659-7170 Cell; 907-943-1054 Fax; 907-659-7103 1 of 1 1/9/2006 8:03 AM u r 1 l FRANK H. MURKOWSKI, GOVERNOR p ALA K OIL AND GAS333 W. n AVENUE, SUITE 100 CONSERVATION COMMSSIOIQ �i ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas FAX (907) 276-7542 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU 1J-164 ConocoPhillips Alaska, Inc. Permit No: 205-144 Surface Location: 1919' FSL, 2517' FEL, Sec. 35, TI IN, RlOE, UM Bottomhole Location: 541' FSL, 2212' FWL, Sec. 23, T1IN, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). 1.11GU1 111Q11 DATED this day of October, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Rr--1 0 ConocoPhillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com ? September 22, 2005 ;i AIS !� 2005 Alaska Oil and Gas Conservation Commission Gas COs. � 333 West 7 Avenue Ann c)RN)? Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 13-164, 13-164 L1, 13-164 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injection well, a trilateral horizontal well in the West Sak "A2", "B" and "D" sands. The main bore of the well will be designated 13- 164, and the lateral bores of the well will be designated 13-164L1 and 13-164L2. 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 13-164 is November 5, 2005. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, Randy Thom s Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill ✓ R76 117 1b. Current Well Class: Exploratory Li Development Oil Multiple Zone ❑ Re-entry ❑ Stratigraphic Test ❑ Service Q Development Gas ❑ Single Zone❑✓ 2. Operator Name: 5. Bond: ✓ Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 - 1J-164 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11678' :, TVD: 3768' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1919' FSL, 2517' FEL, Sec. 35, T1 IN, R1 OE, UM ADL 25661, 25650 West Sak Oil Pool " Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 394' FNL, 2206' FWL, Sec. 35, T11N, R11OE, UM ALK 471, 468 11/5/2005 Total Depth: 9. Acres in Properly: 14. Distance to 541' FSL, 2212' FWL, Sec. 23, T11 N, R10E, UM 2560 Nearest Property: 1919' 4b. Location of Well (State Base Plane Coordinates): 10, KB Elevation 15. Distance to Nearest f Surface: x- 558693 ' y- 5945730 ' Zone- 4 (Height above GL): 28' RKB feet / PM��r ,> Well within Pool: 1J -j) 16. Deviated wells: Kickoff depth: 500 ' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93.7° deg Downhole: 1696 psig �' Surface: 1281 psig f 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticC rete 13.5" 10.75" 45.5# L-80 BTC 2318' 28' 28' 2318' ' 2197' - 480 sx ASLite, 140 sx DeepCrete 9-718" 7-5/8" 29.7# L-80 BTCM 5419' 28' 28' 5419' - 3600' -- 380 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 7005' 4673' 3530' 11678' - 3768' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redril nd Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective D D J s ed) Casing Length Size Cement Volume D D Structural Conductor Qons. Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑✓ BOP Sketch Drilling Program ✓ Time v. Depth Plot Li Shallow Hazard Analysis Lj Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature \ ""� \ Phone ZG5- 6 g'Se Date —7 f? Ucss PreDared by Sharon Allsup-Drak Commission Use Only Permit to Drill/l API Number: Permit Approval See cover letter // Number: � / 1 50- ��- Z 3 Z% Date: for other requirements Conditions of approval : s required Yes ❑ No Mud log required Yes ❑ No tZen Mydr sulfide measures Yes ❑No ® Directional survey required Yes D4 No ❑Othet. �S y APPROVED BY `V O Appro THE COMMISSION Date: Form 10-401 R ed 06/2004 * # "^. t 4 �`. Submit in Duplicate 0 Application for Permit to Drill, Well 1J-164 Revision No.0 Saved: 22 -Sep -05 Permit It - West Sak Well #1J-164 Application for Permit to Drill Document Well uolye Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f}....................................................................................................... 2 2. Location Summary................................................................................................... 2 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 1J-164 PERMIT /T.doc Page 1 of 8 Printed: 22 -Sep -05 .1'INAL ,A i ol 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 S. 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 1J-164 PERMIT /T.doc Page 1 of 8 Printed: 22 -Sep -05 .1'INAL ,A i ol 0 Application for Permit to Drill, Well 1J-164 Revision No.0 Saved: 22 -Sep -05 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 5 114 Mile Radius Effect for Injector......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (1) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 13-164. 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 property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the, surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey In the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Top of Productive Interval 394' FNL, 2,206' FWL, Section 35, T11N, R10E West Salk ""A2" Sand , ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB.• 5,497 Northings.- 5,948,692 Eastings: 558,110 Total Vertical Depth, RKB: 3,677 Total Vertical Depth, SS. 3,568 Location at Total Depth 541' FSL 2,212' FWL, Section 23, T11N R10E ASP Zone 4 NAD 27 Coordinates Northings: 5,954,906 Eastings: 558,061 Measured Depth, RKB: 11,678 Location at Surface 1 919' FSL 2,517' FEL, Section 35 T11N R10E ' ASP Zone 4 NAD 27 Coordinates Northings; 5,945,730 Eastings: 558,693 IRKB Elevation 109.0' AMSL 1 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 394' FNL, 2,206' FWL, Section 35, T11N, R10E West Salk ""A2" Sand , ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB.• 5,497 Northings.- 5,948,692 Eastings: 558,110 Total Vertical Depth, RKB: 3,677 Total Vertical Depth, SS. 3,568 Location at Total Depth 541' FSL 2,212' FWL, Section 23, T11N R10E ASP Zone 4 NAD 27 Coordinates Northings: 5,954,906 Eastings: 558,061 Measured Depth, RKB: 11,678 Total Vertical Depth, RKB.• 3,768 Total Vertical Depth, SS: 3,659 ORIGINAL 1J-164 PERMIT IT.doc Page 2 of 8 Printed: 22 -Sep -05 Application for Permit to Drill, Well 1J-164 Revision No.0 Saved: 22 -Sep -05 and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 251005(c)(3) 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: (3) a diagram and description of the blowout prevention equioment (BODE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8"x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 13-164. 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). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those 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 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: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be 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 13 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 1,281 psi, calculated thusly: MPSP =(3,768 ft TVD)(0.45 - 0.11 psi/ft) =1,281 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 13-164 Drilling Hazards Summary. ORIGINAL 1J-164 PERMIT /T.doc Page 3 of 8 Printed. 22 -Sep -05 •Application for Permit to Drill, Well U-164 Revision No.0 Saved: 22 -Sep -05 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) 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: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25 030(0, 11-164 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application 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: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre - perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) 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: (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 13-164. 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 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-164 PERMIT IT.doc Page 4 of 8 ORIGINAL Printed: 22 -Sep -05 Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Program 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 2,318 28/28 2,318 /2,197 480 sx ASUte Lead, drift 140 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 5,419 28/28 5,419 / 3,600 2,663' MD / 2,497' TVD. Cemented w/ 380 sx Dee CRETE 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 7,005 4,673 / 3,530 11,678 J 3,768 Slotted- no cement slotted Lateral (13-164) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,082 4,583/ 3,518 11,665 / 3,619 Slotted- no cement slotted Lateral (13-164 Ll) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,408 4,250/ 3,446 11,658 / 3,570 Slotted- no cement Slotted Lateral (11-164 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) 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: (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 13-164. 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 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-164 PERMIT IT.doc Page 4 of 8 ORIGINAL Printed: 22 -Sep -05 0 Application for Permit to Drill, Well 1J-164 Revision No.0 Saved: 22 -Sep -05 Surface Hole Mud Program (extended bentonite) *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4" Cs Shoe to 7-5/8" Csg Point Spud to Base of Permafrost Base of Permafrost to 10-3/4" Density (ppg) 9.0-9.1 Casing Point (Ib/100 so Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 - 9.2 9.5 9.6 Funnel Viscosity 150 250 200 300 (seconds) 70/30 Chlorides (mg/1) <500 P H Yield Point 50 70 30 50 (CP) Plastic Viscostiy 20 45 15 20 (Ib/100 4 pH 8.5 9.0 8.5 9.0 API Filtrate NC 8.0 5.0 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" Csg Point Value Value Density (ppg) 9.0-9.1 Funnel (Ib/100 so Viscosity 45-60 (seconds) (CP) Plastic Viscostiy 12- 18 (Ib/100 so Yield Point 26-35 (CP) API Filtrate 4 - 6 (cc / 30 min)) 70/30 Chlorides (mg/1) <500 P H 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) AIBID sand laterals 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 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: (9) for an exploratory or stratigraphic test well, a tabulation seting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An 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: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL 1J-164 PERMIT IT.doc Page 5 of & Printed., 22 -Sep -05 Value Density (ppg) 8.6 Plastic Viscostiy 15-25 (Ib/100 so Yield Point 18-28 (CP) HTHP Fluid loss (m1/30 min <4.0 @ 200psi & 150° Oil / Water 70/30 Ratio Electrical >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) 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: (9) for an exploratory or stratigraphic test well, a tabulation seting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An 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: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL 1J-164 PERMIT IT.doc Page 5 of & Printed., 22 -Sep -05 application for Permit to Drill, Well 1 J-164 Revision No.0 Saved: 22 -Sep -05 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) for a well drilled from an offshore platform, mobile bottom -founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(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 following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {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 application: 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 / rig up 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 +/- 2,318' MD / 2,193' 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.i-� 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 hrs before test.( 6. PU 9-7/8" bit and 6-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re -test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 5,419 MD / 3,600' TVD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 2,663' MD / 2,497' 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. f 12. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re -test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 11,678' MD / 3,768' TVD as per directional plan. 1J-164 PERMITIT.doc Page 6 of 8 ORIGINAL Printed: 22 -Sep -05 application for Permit to Drill, Well 1 J-164 Revision No.0 Saved: 22 -Sep -05 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids -free oil based mud. POOH on elevators. 16. Run USIT log for cement bond._ 17. PU and run 4-1/2" slotted liner. 18. Land liner, set liner hanger @ +/- 4 Note: Remaining operations are covered under the 13-164L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 4,583' MD / 3,518' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 11,665' MD / 3,619' TVD, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids -free oil based mud. POOH on elevators. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the U-1641-2 Application for Permit to Drill, and are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 4,250' MD / 3,446' TVD, the top of the D sand. 30. Mill 6-3/4" window. POOH. 31. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 11,658' MD / 3,570' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. -HH to bottom & displace to solids -free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. POOH. 38. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 39. POOH, laying down drill pipe as required. 40. PU completion as required and RIH to depth. Land tubing. Set BPV. 41. Nipple down BOPE, nipple up tree and test. Pull BPV. ORIGINAL 1J-164 PERMIT IT.doc Page 7 of 8 Printed: 22 -Sep -05 • 42. Freeze protect well with diesel. 43. Set BPV and move rig off. 44. Rig up wire line unit. Pull BPV. application for Permit to Drill, Well 1J-164 Revision No.0 Saved: 22 -Sep -05 45. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 46. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) 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. (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 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 13 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 13 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 Well Schematic Attachment 5 % Mile Radius Effect for Injector ORIGINAL 1J-164 PERMIT IT.doc Page 8 of 8 Printed. 22 -Sep -05 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-164 Plan: 1J-164 (wp06) Proposal Report 13 September, 2005 EI Sperry Drilling Services ORIGINAL -1500 -1000 -500 0 500 1000 1500 4500 5000 550 Project: Kuparuk River Unit FORMATION TOP DETAILS N6VDPath MDPath Formation ConocoPhillips Site: Kuparuk 1J (ad Well: Plan 1J-164 L6) Alilika Wellbore: 1J-164 1 1643.00 1593.05 Base of Permafrost 2 1644.001703.47 3 1935.00 2025.77 K1 K15 Plan: 1J-164 (wp06) 4 2203.00 2324.56 T3. 550 (CSG PTI 5 2922.00 3162.82 Ugnu C 6 3110.00 3434.03 Ugnu B 7 3149.00 3497.27 Ugnu A SHL 191911 FSL & 2517ft FEL -Sec 35 - T11N - R110EI 8 3283.00 3747.36 K-139 3446.00 4260.33 West Sak D (77°) 10 3490.00 4445.93 West Sak C 11 3521.00 4598.53 West Sak B (80°) 12 3558.00 4811.60 West Sak A4 133602+00 5064.99 West Sak A3 14 3670.00 5456.68 West Sak A2 KOP @ 500ft MD, TVD - Build @ 3°/100ft CASING DETAILS Continue Buildlrurn @ 3°/10011, 833ft MD, 832ft TVD No TVD MD Name Size Continue Build/Tum @ 4°/10011, 1167ft MD, 115411 TVD 1 2 2203.00 2324.56 103/4" 10-3/4 3670.00 5456.58 7 5/8" 7-518 3 3768.00 11678.84 4112' 4.1/21 Sail @ 25° Inc: 1301ft MD, 127711 TVD Begin Dir @ 4°/10011, 1415ft MD, 1381ft TVD Sail @ 26° Inc: 1900ft MD, 182211 TVD 10 314" CSG - 2443ft FSL & 2566ft FWL - Sec 35 - T11 N - R10 BHC @ 541ft FSL & 2212ft FWL - Sec 23 - T11N - R10E, 11679ft MD, 3678ft TV Begin Dir @ 4°/10011, 2653ft MD, 2497ft TVD _----- Sail @ 77° Inc: 4150ft MD, 3423ft TVD 1J-164 Toe (wp06� Begin Build @ 3°/100ft, 4483ft MD, 3498ft TVD I FuowA (�, Sail @ 80° Inc : 4583ft MD, 3518ft TVD =_=_- _------____-_-_-- --------------------------------------------------------------------- _1-=_-- - - - - - - - - - - _ - _ _ - _ - - _ - - - - - - - - - - - - - - - - - _ - _ _ - - _ L:_ - - - - - - - - - - -- - - -c -- Wad8ak8( -- -- r � 1 \ 1 \ Wad Sak I 1J464T1(Dtop1(Wp06 Wed Bak ' � Wad tick � 1J•184 T10 (wp08 1J-164 T3 (Peak 1pwpW 7 518" CSG - 394ft FNL & 2206ft FWL - Sec 35 - TI IN - R10E � , 1J-164 T8 (wp08 1J-164 T7 (wp06 1J-164 T4 (Trough 1xwp06 ' 11-184 T2 (A2-Landln9) (wpOG \ 1J-164 T6 (Peak 2Nwp06 1J-184 T8 (wp06 1J-164 TS (wp06 Begin Undulations in A2 Sand, 5754ft MD, 3698ft TVD Build @ 4°/100ft, 5497ft MD, 3677ft TVD End Undulations Begin Geo -Steering in A2, 8304ft MD, 369311 TVD -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Vertical Section at 0.00° (1000 ft/in) ConocoPhillips Alaska 81 c_ 3125 2500 187 1J-164 Toe (wp08 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-164 (1-6) Wellbore: 1J-164 Plan: 1J-164 (wp06) M imuths to True North agnetic North: 25.06° Magnetic Field Strength: 57537.4nT Dip Angle: 80.71 ° Date: 9/17/2003 Model: BGGM2004 N r - - - - - - - - - 0' - - - -I BHL @ 541ft FSL & 2212ft FWL - Sec 23 - T11 N - R1 OF, 116798 MD, 3678: 1J-164 T8(wp08------- --------- 1J-164 T7 (wP06 360° CASING DETAILS No TVD MD Name Size 0° 1 2203.00 2324.56 10 3/4" 10-3/4 2 3670.00 5456.58 75/8'. 7-5/8 0° 3 3768.0011678.84 41/2" 4-1/2 360° 0° 0° 1J-164 T6(wp06----------------- 1° 1J-164 T6 (Peak 2Nwp08 1J-164 T4 (Trough 1)(wp06 - - - - - - - - - - - - - - - 1J-164 T3 (Peak 1Nwp06 End Undulations Begin Geo -Steering in A2, 8304ft MD, 3693ft TVD Begin Undulations in A2 Sand, 5754ft MD, 3698ft TVD ' Build � 4°/100:, 5497: MD, 3677: TVD 1J•184 T2 (A2-Lant9ng) (wp06 " � - - 0° - -- " Sail 80° Inc : 4583ft MD, 3518ft TVD - ------ r 7618"CSG-3%ftFNL&2206ftFWL-Sac 36-T11N•RIO - 0° Begin Build @ 3°/100ft, 4483ft MD, 3498ft TVD _ - - - - Sail @ 77° Inc: 4150:MD, 3423:TVD 1J-164T1(Dtop)(wpO6----------------- 0° - - ----- Begin Dir C 4°/100:, 2653ft MD, 2497ft TVD 1250 Sail 26° Inc: 1900ft MD, 1822ft TVD 625- - - - " Begin Dir @ 4°/100ft, 1415ft MD, 1381ft TVD ------- - °-----------------Sail@25°In c: 1301ft MD, 1277ft TVD 0 -__ Continue Buildrrurn @ 4°/100ft , 1167ft MD, 1154: TVD 10 3/4" CSG - 244311 FSL & 2566ft FWL - Sec 35 - T11 N - RIOIE -625— Continue Build/Tum 3.1100ft, 833ft MD, 832: TVD KOP 500ft MD, TVD - Build @ 3°/100: -1250 SHL @ 181911 FSL & 2617ftFEL - Sec 36 - T11 N - R10 -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 West( -)/East(+) (1250 ft/in) 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-164 (1-6) Well Position +N/ -S 0.00 ft Northing: 5,945,730.87 ft Latitude: 70° 15'44.408" N +E/ -W 0.00 ft Easting: 558,693.02 ft Longitude: 149° 31'31.870" W Position Uncertainty 0.00 ft Wellhead Elevation: it Ground Level: 81.00ft Wellbore 1J-164 Magnetics : Model Name Sample pate Declination Dip Angle Field Strength (°) (°) (nT) bggm2004 9/17/2003 25.06 80.71 57,537 Design 1J-164 (wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +N1 -S +E1 -W Direction (ft) (ft) (ft) (°). 28.00 0.00 0.00 0.00 9/13!2005 10:48:44AM Page 2 of 10 COMPASS 2003.11 Build 48 ORIGINAL 0 *r-' ConocoPhillis p Halliburton Company Planning Report RT ~ �L�Bu onr -Geographic Alaska Sperry Drilliino Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference. Well Plan 1J-164 (1-6) Company: ; ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference. 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Site: Kuparuk 1J Pad North Reference: True Welt Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: IJ -164 Design: 1J-164 (wp06) 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-164 (1-6) Well Position +N/ -S 0.00 ft Northing: 5,945,730.87 ft Latitude: 70° 15'44.408" N +E/ -W 0.00 ft Easting: 558,693.02 ft Longitude: 149° 31'31.870" W Position Uncertainty 0.00 ft Wellhead Elevation: it Ground Level: 81.00ft Wellbore 1J-164 Magnetics : Model Name Sample pate Declination Dip Angle Field Strength (°) (°) (nT) bggm2004 9/17/2003 25.06 80.71 57,537 Design 1J-164 (wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +N1 -S +E1 -W Direction (ft) (ft) (ft) (°). 28.00 0.00 0.00 0.00 9/13!2005 10:48:44AM Page 2 of 10 COMPASS 2003.11 Build 48 ORIGINAL Plan Summary 10 40 v-' ConocoPhiil1 5 p Halliburton Company Planning Report HALLIBURTON -Geographic Alaska Sperry Drilling Servlces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-164 (1-6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL+ 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.00ft (13141 (28GL + 81'RF)) Site: Kuparuk 1 J Pad North Reference: True Well. Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 (-1100ft) 0 ; Design: 1J-164 (wp06) 0.00 28.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +Nl-S +EI -W Rate Rate Rate TFO (ft) (D) (b) (ft) (ft) (ft) (-1100ft) (*1100ft) ', (-1100ft) 0 ; 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 833.33 10.00 8.00 831.64 28.73 4.04 3.00 3.00 0.00 8.00 1,167.56 20.00 5.00 1,154.08 114.63 13.08 3.00 2.99 -0.90 354.10 1,301.30 25.00 0.00 1,277.60 165.71 15.08 4.00 3.74 -3.74 336.73 1,415.90 25.00 0.00 1,381.47 214.14 15.08 0.00 0.00 0.00 0.00 1,900.79 26.24 314.23 1,822.89 393.07 -62.47 4.00 0.25 -9.44 -107.46 2,653.42 26.24 314.23 2,497.98 625.14 -300.90 0.00 0.00 0.00 0.00 4,150.33 77.00 0.07 3,423.50 1,683.29 -561.32 4.00 3.39 3.06 53.92 4,250.33 77.00 0.07 3,446.00 1,780.73 -561.21 0.00 0.00 0.00 0.00 4,483.53 77.00 0.07 3,498.46 2,007.95 -560.95 0.00 0.00 0.00 0.00 4,583.67 80.00 0.07 3,518.42 2,106.07 -560.84 3.00 3.00 0.00 0.00 5,497.67 80.00 0.07 3,677.13 3,006.18 -559.82 0.00 0.00 0.00 0.00 5,754.95 90.29 359.92 3,698.88 3,262.19 -559.87 4.00 4.00 -0.06 -0.83 6,094.95 93.69 359.92 3,687.07 3,601.93 -560.36 1.00 1.00 0.00 0.00 6,144.95 93.69 359.92 3,683.86 3,651.83 -560.43 0.00 0.00 0.00 0.00 6,604.95 89.09 359.92 3,672.70 4,111.57 -561.10 1.00 -1.00 0.00 180.00 6,964.95 87.29 359.92 3,684.07 4,471.38 -561.63 0.50 -0.50 0.00 180.00 7,094.95 87.29 359.92 3,690.22 4,601.23 -561.82 0.00 0.00 0.00 0.00 7,454.95 88.19 359.92 3,704.41 4,960.95 -562.34 0.25 0.25 0.00 0.00 7,794.95 92.44 359.92 3,702.55 5,300.86 -562.84 1.25 1.25 0.00 0.00 7,964.95 92.44 359.92 3,695.31 5,470.71 -563.08 0.00 0.00 0.00 0.00 8,304.95 88.19 359.92 3,693.44 5,810.62 -563.58 1.25 -1.25 0.00 -180.00 8,366.75 87.23 0.70 3,695.91 5,872.38 -563.25 2.00 -1.55 1.27 140.68 8,575.90 87.23 0.70 3,706.00 6,081.27 -560.69 0.00 0.00 0.00 0.00 8,748.76 90.58 359.83 3,709.30 6,254.07 -559.90 2.00 1.94 -0.50 -14.62 8,976.02 90.58 359.83 3,707.00 6,481.32 -560.58 0.00 0.00 0.00 0.00 9,044.51 93.25 0.44 3,704.71 6,549.76 -560.42 4.00 3.90 0.89 12.84 9,266.61 93.25 0.44 3,692.12 6,771.50 -558.72 0.00 0.00 0.00 0.00 9,376.60 90.00 359.87 3,689.00 6,881.43 -558.43 3.00 -2.96 -0.52 -170.08 9,876.60 90.00 359.87 3,689.00 7,381.42 -559.56 0.00 0.00 0.00 0.00 9,901.76 89.26 0.02 3,689.16 7,406.58 -559.58 3.00 -2.94 0.60 168.41 10,276.68 89.26 0.02 3,694.00 7,781.47 -559.44 0.00 0.00 0.00 0.00 10,360.47 86.75 359.99 3,696.92 7,865.21 -559.44 3.00 -3.00 -0.04 -179.21 11,278.35 86.75 359.99 3,749.00 8,781.60 -559.65 0.00 0.00 0.00 0.00 11,306.03 87.30 0.02 3,750.44 8,809.25 -559.65 2.00 2.00 0.11 3.23 11,678.85 87.30 0.02 3,768.00 9,181.65 -559.53 0.00 0.00 0.00 0.00 9/13/2005 10:48:44AM Page 3 of 10 COMPASS 2003.11 Build 48 INAL ' Halliburton Company 40 HALLIBURTON ConocoPhill#p5 Planning Report - Geographic Alaska Sperry DrilNnS Services Database: ' EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-164 (1-6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 DLSEV Vert Section Design: 1J-164 (wp06) (ft) (ft) Planned Survey 1J-164 (wp06) 23.78 342.35 1,549.36 1,440.36 288.52 3.81 5,946,019.38 558,694.58 4.00 288.52 1,700.00 Map Map 1,640.83 1,531.83 AAD Inclination Azimuth TVD SSTVD +N/ -S +E/ -W Northing Easting DLSEV Vert Section jft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (0/100to (ft) 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,730.87 558,693.02 0.00 0.00 SHL @ 191 9f FSL & 2517ft FEL - Sec 35 - T11 N - RI OE 1,800.00 24.84 323.01 1,731.92 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,730.87 558,693.02 0.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,945,730.87 558,693.02 0.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,945,730.87 558,693.02 0.00 0.00 400.00 0.00 0.00 400.00 291.00 0.00 0.00 5,945,730.87 558,693.02 0.00 0.00 500.00 0.00 0.00 500.00 391.00 0.00 0.00 5,945,730.87 558,693.02 0.00 0.00 KOP @ 500ft MD, TVD - Build @ 3°/100ft 1,802.88 423.66 -93.90 5,946,153.74 558,595.83 0.00 423.66 600.00 3.00 8.00 599.95 490.95 2.59 0.36 5,945,733.46 558,693.36 3.00 2.59 700.00 6.00 8.00 699.63 590.63 10.36 1.46 5,945,741.24 558,694.40 3.00 10.36 800.00 9.00 8.00 798.77 689.77 23.28 3.27 5,945,754.18 558,696.11 3.00 23.28 833.33 10.00 8.00 831.64 722.64 28.73 4.04 5,945,759.63 558,696.83 3.00 28.73 Continue Build/Tum @ 3°/100ft , 833ft MD, 832ft TVD 2,200.00 26.24 314.23 2,091.28 1,982.28 485.33 900.00 11.99 7.01 897.08 788.08 41.34 5.69 5,945,772.25 558,698.39 3.00 41.34 1,000.00 14.98 6.01 994.31 885.31 64.51 8.31 5,945,795.44 558,700.83 3.00 64.51 1,100.00 17.98 5.34 1,090.20 981.20 92.74 11.10 5,945,823.68 558,703.40 3.00 92.74 1,167.56 20.00 5.00 1,154.08 1,045.08 114.63 13.08 5,945,845.58 558,705.21 3.00 114.63 Continue Build/rum @ 4°/100ft , 1167ft MD, 1154ft TVD 1,200.00 21.20 3.58 1,184.44 1,075.44 126.01 13.93 5,945,856.97 558,705.97 4.00 126.01 1,300.00 24.95 0.04 1,276.43 1,167.43 165.16 15.08 5,945,896.13 558,706.81 4.00 165.16 1,301.30 25.00 0.00 1,277.60 1,168.60 165.71 15.08 5,945,896.67 558,706.80 4.00 165.71 Sail @ 250 Inc : 1301ft MD, 1277ft TVD 1,400.00 25.00 0.00 1,367.06 1,258.06 207.42 15.08 5,945,938.38 558,706.48 0.00 207.42 1,415.90 25.00 0.00 1,381.47 1,272.47 214.14 15.08 5,945,945.10 558,706.43 0.00 214.14 Begin Dir @ 40/100ft, 1415ft MD, 1381ft TVD 1,500.00 24.19 352.15 1,457.96 1,348.96 248.99 12.72 5,945,979.93 558,703.80 4.00 248.99 1,593.05 23.79 343.04 1,543.00 1,434.00 285.84 4.64 5,946,016.71 558,695.43 4.00 285.84 Base of Permafrost 1,600.00 23.78 342.35 1,549.36 1,440.36 288.52 3.81 5,946,019.38 558,694.58 4.00 288.52 1,700.00 24.00 332.48 1,640.83 1,531.83 325.79 -11.71 5,946,056.52 558,678.77 4.00 325.79 1,703.47 24.02 332.14 1,644.00 1,535.00 327.04 -12.37 5,946,057.77 558,678.10 4.01 327.04 T3 1,800.00 24.84 323.01 1,731.92 1,622.92 360.61 -33.76 5,946,091.17 558,656.46 4.00 360.61 1,900.00 26.22 314.29 1,822.18 1,713.18 392.83 -62.22 5,946,123.16 558,627.74 4.00 392.83 1,900.79 26.24 314.23 1,822.89 1,713.89 393.07 -62.47 5,946,123.40 558,627.49 4.00 393.07 Sail @ 26° Inc : 1900ft MD, 1822ft TVD 2,000.00 26.24 314.23 1,911.88 1,802.88 423.66 -93.90 5,946,153.74 558,595.83 0.00 423.66 2,025.77 26.24 314.23 1,935.00 1,826.00 431.61 -102.07 5,946,161.63 558,587.60 0.00 431.61 K15 2,100.00 26.24 314.23 2,001.58 1,892.58 454.49 -125.58 5,946,184.33 558,563.91 0.00 454.49 2,200.00 26.24 314.23 2,091.28 1,982.28 485.33 -157.26 5,946,214.91 558,532.00 0.00 485.33 2,300.00 26.24 314.23 2,180.97 2,071.97 516.16 -188.94 5,946,245.49 558,500.08 0.00 516.16 2,324.56 26.24 314.23 2,203.00 2,094.00 523.73 -196.72 5,946,253.01 558,492.24 0.00 523.73 10 314" CSG - 2443ft FSL & 2566ft FWL - Sec 35 - T11 N - R11 OE - T3 + $50 (CSG PT) -10 3/4" 9!13/2005 10:48:44AM Page 4 of 10 COMPASS 2003.11 Build 48 ORIGINAL Planned Survey 0 D•� , ConocoPhil� Halliburton Company Planning Report Geographic HALLISURTON - ps - Sporry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: '. Well Plan 1J-164 (1-6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 (ft) (ft) ' Design: 1J-164 (wp06) 2,400.00 26.24 Planned Survey 1J-164 (wp06) Map Map MD inclination Azimuth TVD SSTVD +N/ -S +E/ -W Northing Lasting DLSEV Vert Section , (fti (0) (0) (ft) (ft) (ft)_ (ft) (ft) (ft) ' (°1100ft) (ft) 2,400.00 26.24 314.23 2,270.67 2,161.67 547.00 -220.62 5,946,276.08 558,468.17 0.00 547.00 2,500.00 26.24 314.23 2,360.37 2,251.37 577.83 -252.30 5,946,306.66 558,436.25 0.00 577.83 2,600.00 26.24 314.23 2,450.07 2,341.07 608.66 -283.98 5,946,337.24 558,404.34 0.00 608.66 2,653.42 26.24 314.23 2,497.98 2,388.98 625.14 -300.90 5,946,353.58 558,387.29 0.00 625.14 Begin Dir 40/10011, 2653ft MD, 2497ft TVD 2,700.00 27.37 317.50 2,539.56 2,430.56 640.21 -315.51 5,946,368.54 558,372.56 4.00 640.21 2,800.00 30.04 323.72 2,627.28 2,518.28 677.35 -345.87 5,946,405.44 558,341.92 4.00 677.35 2,900.00 32.95 328.97 2,712.56 2,603.56 720.85 -374.71 5,946,448.71 558,312.74 4.00 720.85 3,000.00 36.05 333.43 2,794.97 2,685.97 770.50 -401.90 5,946,498.14 558,285.16 4.00 770.50 3,100.00 39.30 337.27 2,874.12 2,765.12 826.05 -427.31 5,946,553.49 558,259.32 4.00 826.05 3,162.82 41.39 339.41 2,922.00 2,813.00 863.85 -442.31 5,946,591.16 558,244.04 4.00 863.85 Ugnu C 3,200.00 42.65 340.60 2,949.62 2,840.62 887.23 -450.81 5,946,614.48 558,235.35 4.00 887.23 3,300.00 46.09 343.52 3,021.10 2,912.10 953.75 -472.29 5,946,680.82 558,213.35 4.00 953.75 3,400.00 49.59 346.13 3,088.22 2,979.22 1,025.29 -491.64 5,946,752.20 558,193.45 4.00 1,025.29 3,434.03 50.80 346.95 3,110.00 3,001.00 1,050.71 -497.73 5,946,777.57 558,187.17 4.00 1,050.71 Ugnu B 3,497.27 53.05 348.41 3,149.00 3,040.00 1,099.34 -508.34 5,946,826.11 558,176.18 4.00 1,099.34 Ugnu A 3,500.00 53.15 348.47 3,150.64 3,041.64 1,101.48 -508.77 5,946,828.25 558,175.72 3.98 1,101.48 3,600.00 56.75 350.61 3,208.07 3,099.07 1,181.97 -523.60 5,946,908.61 558,160.27 4.00 1,181.97 3,700.00 60.38 352.57 3,260.22 3,151.22 1,266.36 -536.05 5,946,992.89 558,147.17 4.00 1,266.36 3,747.36 62.11 353.45 3,283.00 3,174.00 1,307.57 -541.10 5,947,034.05 558,141.80 4.00 1,307.57 K-13 3,800.00 64.04 354.40 3,306.84 3,197.84 1,354.23 -546.07 5,947,080.68 558,136.47 4.00 1,354.23 3,900.00 67.72 356.11 3,347.70 3,238.70 1,445.17 -553.59 5,947,171.54 558,128.23 4.00 1,445.17 4,000.00 71.42 357.74 3,382.60 3,273.60 1,538.73 -558.60 5,947,265.05 558,122.50 4.00 1,538.73 4,100.00 75.13 359.30 3,411.38 3,302.38 1,634.44 -561.05 5,947,360.73 558,119.30 4.00 1,634.44 4,150.33 77.00 0.07 3,423.50 3,314.50 1,683.29 -561.32 5,947,409.57 558,118.65 4.00 1,683.29 Sall @ 770 Inc : 41 50f MD, 3423ft TVD 4,200.00 77.00 0.07 3,434.68 3,325.68 1,731.68 -561.27 5,947,457.96 558,118.33 0.00 1,731.68 4,250.33 77.00 0.07 3,446.00 3,337.00 1,780.73 -561.21 5,947,507.00 558,118.00 0.00 1,780.73 West Sak D (77°) -1J-164 T1 (Dtop) (wp06) 4,300.00 77.00 0.07 3,457.17 3,348.17 1,829.12 -561.16 5,947,555.39 558,117.68 0.00 1,829.12 4,400.00 77.00 0.07 3,479.67 3,370.67 1,926.56 -561.05 5,947,652.81 558,117.03 0.00 1,926.56 4,445.93 77.00 0.07 3,490.00 3,381.00 1,971.31 -561.00 5,947,697.56 558,116.73 0.00 1,971.31 West Sak C 4,483.53 77.00 0.07 3,498.46 3,389.46 2,007.95 -560.95 5,947,734.20 558,116.49 0.00 2,007.95 Begin Build @ 30/10011, 4483ft MD, 3498ft TVD 4,500.00 77.49 0.07 3,502.09 3,393.09 2,024.01 -560.94 5,947,750.25 558,116.38 2.99 2,024.01 4,583.67 80.00 0.07 3,518.42 3,409.42 2,106.07 -560.84 5,947,832.30 558,115.83 3.00 2,106.07 Sail Q 800 Inc : 4583ft MD, 351811 TVD 4,598.53 80.00 0.07 3,521.00 3,412.00 2,120.70 -560.83 5,947,846.93 558,115.74 0.00 2,120.70 West Sak B (8011) M312005 10:48:44AM Page 5 of 10 COMPASS 2003.11 Build 48 ORIGINAL ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site, Kuparuk 1J Pad Walk Plan 1J-164 (1-6) Wellbore: 1J-164 Design: 1 J-164 (wp06) Halliburton Company • HALL.18UFtTON Planning Report - Geographic tanned Survey Simrry Dtfilk* Services Local Co-ordinate Reference: Well Plan 1J-164 (1-6) TVD Reference: 1J-164 (28'+81') @ 109.00ft (13141 (28GL + 81'RF)) MD Reference: 1J-164 (28'+81') @ 109.00ft (13141 (28GL + 81'RF)) North Reference: True Survey Calculation Method: Minimum Curvature tanned Survey 1J-164 (wp06) Map 3,573.35 MD Inclination Azimuth TVD SSTVD +NLS (ft) (') (0) (ft) (ft) (ft) 4,600.00 80.00 0.07 3,521.26 3,412.26 2,122.15 4,700.00 80.00 0.07 3,538.62 3,429.62 2,220.63 4,800.00 80.00 0.07 3,555.99 3,446.99 2,319.11 4,811.60 80.00 0.07 3,558.00 3,449.00 2,330.53 West Sak A4 2,330.53 4,900.00 Map ` Map 3,573.35 3,464.35 +E1 -W Northing Easting DLSEV Von Section (ft) (ft) (ft) (°1100ft) (ft} -560.82 5,947,848.38 558,115.73 0.00 2,122.15 -560.71 5,947,946.85 558,115.07 0.00 2,220.63 -560.60 5,948,045.32 558,114.41 0.00 2,319.11 -560.59 5,948,056.74 558,114.34 0.00 2,330.53 4,900.00 80.00 0.07 3,573.35 3,464.35 2,417.59 -560.49 5,948,143.79 558,113.76 0.00 2,417.59 5,000.00 80.00 0.07 3,590.72 3,481.72 2,516.07 -560.38 5,948,242.25 558,113.10 0.00 2,516.07 5,064.99 80.00 0.07 3,602.00 3,493.00 2,580.07 -560.31 5,948,306.25 558,112.68 0.00 2,580.07 West Sak A3 5,100.00 80.00 0.07 3,608.08 3,499.08 2,614.55 -560.27 5,948,340.72 558,112.45 0.00 2,614.55 5,200.00 80.00 0.07 3,625.44 3,516.44 2,713.03 -560.15 5,948,439.19 558,111.79 0.00 2,713.03 5,300.00 80.00 0.07 3,642.81 3,533.81 2,811.51 -560.04 5,948,537.66 558,111.14 0.00 2,811.51 5,400.00 80.00 0.07 3,660.17 3,551.17 2,909.99 -559.93 5,948,636.13 558,110.48 0.00 2,909.99 5,456.58 80.00 0.07 3,670.00 3,561.00 2,965.71 -559.87 5,948,691.85 558,110.11 0.00 2,965.71 7 518" CSG - 394ft FNL & 2206ft FWL - Sec 35 - T11 N - R1 OE - West Sak A2 - 7 5/8" 5,497.67 80.00 0.07 3,677.13 3,568.13 3,006.18 -559.82 5,948,732.31 558,109.84 0.00 3,006.18 Build @ 40/100ft, 5497ft MD, 3677ft TVD 5,500.00 80.09 0.06 3,677.54 3,568.54 3,008.47 -559.82 5,948,734.60 558,109.82 3.96 3,008.47 5,600.00 84.09 0.01 3,691.29 3,582.29 3,107.50 -559.76 5,948,833.62 558,109.11 4.00 3,107.50 5,700.00 88.09 359.95 3,698.10 3,589.10 3,207.25 -559.80 5,948,933.35 558,108.29 4.00 3,207.25 5,754.95 90.29 359.92 3,698.88 3,589.88 3,262.19 -559.87 5,948,988.28 558,107.80 4.00 3,262.19 Begin Undulations in A2 Sand, 5754ft MD, 3698ft TVD -1J-164 T2 (A2 -Landing) (wp06) 5,800.00 90.74 359.92 3,698.47 3,589.47 3,307.24 -559.93 5,949,033.33 558,107.38 1.00 3,307.24 5,900.00 91.74 359.92 3,696.31 3,587.31 3,407.22 -560.08 5,949,133.29 558,106.46 1.00 3,407.22 6,000.00 92.74 359.92 3,692.40 3,583.40 3,507.14 -560.22 5,949,233.20 558,105.53 1.00 3,507.14 6,094.95 93.69 359.92 3,687.07 3,578.07 3,601.93 -560.36 5,949,327.98 558,104.66 1.00 3,601.93 Sall @ 93.690 Inc : 6094ft MD, 3687ft TVD 6,100.00 93.69 359.92 3,686.75 3,577.75 3,606.98 -560.37 5,949,333.02 558,104.61 0.00 3,606.98 6,144.95 93.69 359.92 3,683.86 3,574.86 3,651.83 -560.43 5,949,377.87 558,104.19 0.00 3,651.83 Begin Dir @ 1.00°/100ft, 6144ft MD, 3683ft TVD 6,200.00 93.14 359.92 3,680.58 3,571.58 3,706.79 -560.51 5,949,432.82 558,103.69 1.00 3,706.79 6,300.00 92.14 359.92 3,675.97 3,566.97 3,806.68 -560.66 5,949,532.70 558,102.76 1.00 3,806.68 6,400.00 91.14 359.92 3,673.11 3,564.11 3,906.64 -560.80 5,949,632.64 558,101.84 1.00 3,906.64 6,500.00 90.14 359.92 3,672.00 3,563.00 4,006.63 -560.95 5,949,732.62 558,100.91 1.00 4,006.63 6,600.00 89.14 359.92 3,672.62 3,563.62 4,106.62 -561.10 5,949,832.60 558,099.99 1.00 4,106.62 6,604.95 89.09 359.92 3,672.70 3,563.70 4,111.57 -561.10 5,949,837.55 558,099.94 1.00 4,111.57 Begin Dir @ 0.500/100ft, 6604ft MD, 3672ft TVD -1J-164 T3 (Peak 1)(wp06) 6,700.00 88.61 359.92 3,674.61 3,565.61 4,206.60 -561.24 5,949,932.57 558,099.06 0.50 4,206.60 6,800.00 88.11 359.92 3,677.46 3,568.46 4,306.56 -561.39 5,950,032.51 558,098.14 0.50 4,306.56 6,900.00 87.61 359.92 3,681.18 3,572.18 4,406.49 -561.53 5,950,132.43 558,097.21 0.50 4,406.49 6,964.95 87.29 359.92 3,684.07 3,575.07 4,471.38 -561.63 5,950,197.30 558,096.61 0.50 4,471.38 Sail @ 87.290 Inc : 6964ft MD, 3684ft TVD 7,000.00 87.29 359.92 3,685.73 3,576.73 4,506.39 -561.68 5,950,232.31 558,096.29 0.00 4,506.39 7,094.95 87.29 359.92 3,690.22 3,581.22 4,601.23 -561.82 5,950,327.14 558,095.41 0.00 4,601.23 Begin Dir @ 0.250/100ft, 7094ft MD, 3690ft TVD 9/13/2005 10:48:44AM Page 6 of 10 COMPASS 2003.11 Build 48 Planned Survey 0 'O' Con ocoPhlill 5 p Halliburton Company Planning Report MALLIBUATON -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: '' Well Plan 1J-164 (1-6) , Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Site: Kuparuk 1J Pad North Reference: True Well* Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 (ft) (ft) Design: 1J-164 (wp06) (ft) 7,100.00 Planned Survey 1J-164 (wp06) Map; Map MD Inclination Azimuth TVD SSTVD +Nl-S +E/ -W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ' (01100ft) (ft) 7,100.00 87.30 359.92 3;690.46 3,581.46 4,606.28 -561.82 5,950,332.19 558,095.36 0.25 4,606.28 7,200.00 87.55 359.92 3,694.94 3,585.94 4,706.18 -561.97 5,950,432.07 558,094.44 0.25 4,706.18 7,300.00 87.80 359.92 3,699.00 3,590.00 4,806.09 -562.12 5,950,531.98 558,093.52 0.25 4,806.09 7,400.00 88.05 359.92 3,702.61 3,593.61 4,906.03 -562.26 5,950,631.90 558,092.59 0.25 4,906.03 7,454.95 88.19 359.92 3,704.41 3,595.41 4,960.95 -562.34 5,950,686.81 558,092.08 0.25 4,960.95 Begin Dir @ 1.25°/100ft, 7454ft MD, 3704ft TVD -1J-164 T4 (Trough 1)(wp06) 7,500.00 88.75 359.92 3,705.62 3,596.62 5,005.98 -562.41 5,950,731.84 558,091.67 1.25 5,005.98 7,600.00 90.00 359.92 3,706.70 3,597.70 5,105.98 -562.55 5,950,831.81 558,090.74 1.25 5,105.98 7,700.00 91.25 359.92 3,705.60 3,596.60 5,205.97 -562.70 5,950,931.79 558,089.82 1.25 5,205.97 7,794.95 92.44 359.92 3,702.55 3,593.55 5,300.86 -562.84 5,951,026.68 558,088.94 1.25 5,300.86 Sail @ 92.44° Inc : 7794ft MD, 37028 TVD 7,800.00 92.44 359.92 3,702.33 3,593.33 5,305.91 -562.84 5,951,031.72 558,088.89 0.00 5,305.91 7,900.00 92.44 359.92 3,698.07 3,589.07 5,405.82 -562.99 5,951,131.62 558,087.97 0.00 5,405.82 7,964.95 92.44 359.92 3,695.31 3,586.31 5,470.71 -563.08 5,951,196.50 558,087.37 0.00 5,470.71 Begin Dir @ 1.250I100ft, 7964ft MD, 3695ft TVD 8,000.00 92.00 359.92 3,693.95 3,584.95 5,505.74 -563.14 5,951,231.52 558,087.04 1.25 5,505.74 8,100.00 90.75 359.92 3,691.55 3,582.55 5,605.70 -563.28 5,951,331.48 558,086.12 1.25 5,605.70 8,200.00 89.50 359.92 3,691.33 3,582.33 5,705.70 -563.43 5,951,431.46 558,085.19 1.25 5,705.70 8,300.00 88.25 359.92 3,693.29 3,584.29 5,805.68 -563.57 5,951,531.42 558,084.27 1.25 5,805.68 8,304.95 88.19 359.92 3,693.44 3,584.44 5,810.62 -563.58 5,951,536.37 558,084.22 1.25 5,810.62 End Undulations Begin Geo -Steering in A2, 8304ft MD, 3693ft TVD -1.1-164 TS (Peak 2)(wp06) 8,366.75 87.23 0.70 3,695.91 3,586.91 5,872.38 -563.25 5,951,598.12 558,084.07 2.00 5,872.38 8,400.00 87.23 0.70 3,697.51 3,588.51 5,905.59 -562.84 5,951,631.32 558,084.22 0.00 5,905.59 8,500.00 87.23 0.70 3,702.34 3,593.34 6,005.46 -561.62 5,951,731.19 558,084.66 0.00 6,005.46 8,575.90 87.23 0.70 3,706.00 3,597.00 6,081.27 -560.69 5,951,807.00 558,085.00 0.00 6,081.27 1J-164 T6 (wp06) 8,600.00 87.70 0.58 3,707.06 3,598.06 6,105.34 -560.42 5,951,831.07 558,085.08 2.00 6,105.34 8,700.00 89.63 0.07 3,709.39 3,600.39 6,205.31 -559.85 5,951,931.03 558,084.87 2.00 6,205.31 8,748.76 90.58 359.83 3,709.30 3,600.30 6,254.07 -559.90 5,951,979.78 558,084.45 2.00 6,254.07 8,800.00 90.58 359.83 3,708.78 3,599.78 6,305.31 -560.05 5,952,031.01 558,083.90 0.00 6,305.31 8,900.00 90.58 359.83 3,707.77 3,598.77 6,405.30 -560.35 5,952,130.99 558,082.82 0.00 6,405.30 8,976.02 90.58 359.83 3,707.00 3,598.00 6,481.32 -560.58 5,952,207.00 558,082.00 0.00 6,481.32 1 J-164 T7 (wp06) 9,000.00 91.51 0.04 3,706.56 3,597.56 6,505.29 -560.60 5,952,230.97 558,081.79 3.99 6,505.29 9,044.51 93.25 0.44 3,704.71 3,595.71 6,549.76 -560.42 5,952,275.44 558,081.63 4.00 6,549.76 9,100.00 93.25 0.44 3,701.57 3,592.57 6,605.16 -559.99 5,952,330.83 558,081.62 0.00 6,605.16 9,200.00 93.25 0.44 3,695.90 3,586.90 6,705.00 -559.23 5,952,430.66 558,081.60 0.00 6,705.00 9,266.61 93.25 0.44 3,692.12 3,583.12 6,771.50 -558.72 5,952,497.16 558,081.59 0.00 6,771.50 9,300.00 92.26 0.27 3,690.51 3,581.51 6,804.85 -558.52 5,952,530.50 558,081.54 3.00 6,804.85 9,376.60 90.00 359.87 3,689.00 3,580.00 6,881.43 -558.43 5,952,607.07 558,081.03 3.00 6,881.43 9,400.00 90.00 359.87 3,689.00 3,580.00 6,904.83 -558.48 5,952,630.47 558,080.80 0.00 6,904.83 9,500.00 90.00 359.87 3,689.00 3,580.00 7,004.83 -558.71 5,952,730.46 558,079.79 0.00 7,004.83 9,600.00 90.00 359.87 3,689.00 3,580.00 7,104.83 -558.93 5,952,830.44 558,078.78 0.00 7,104.83 9,700.00 90.00 359.87 3,689.00 3,580.00 7,204.83 -559.16 5,952,930.43 558,077.78 0.00 7,204.83 9,800.00 90.00 359.87 3,689.00 3,580.00 7,304.83 -559.39 5,953,030.41 558,076.77 0.00 7,304.83 9,876.60 90.00 359.87 3,689.00 3,580.00 7,381.42 -559.56 5,953,107.00 558,076.00 0.00 7,381.42 1J-164 T8 (wp06) 9113/2005 10:48:44AM Page 7 of 10 COMPASS 2003.11 Build 48 ORIGINAL Planned Survey 0 ♦-' ConocoPhillips Halliburton Company Planning Report Geographic HALLIBURTON - Alaska Sperry Drilling Services Database: ` EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-164 (1-6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1,1-164 (28'+81') @ 109.00ft (13141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Site- Kuparuk 1J Pad North Reference: True Well: Pian 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 (ft) (ft) Design: 1J-164 (wp06) 9,900.00 89.31 Planned Survey 1J-164 (wp06) Map 'i Map! MD Inclination Azimuth TVD SSTVD +Ni -S +E/»W Northing Easting DLSEV Vert Section (ft) (0)' (°) (ft) (ft) (ft) (ft) (ft) (ft) ell00ft) (fH 9,900.00 89.31 0.01 3,689.14 3,580.14 7,404.82 -559.58 5,953,130.40 558,075.79 3.00 7,404.82 9,901.76 89.26 0.02 3,689.16 3,580.16 7,406.58 -559.58 5,953,132.15 558,075.78 3.00 7,406.58 10,000.00 89.26 0.02 3,690.43 3,581.43 7,504.82 -559.55 5,953,230.38 558,075.05 0.00 7,504.82 10,100.00 89.26 0.02 3,691.72 3,582.72 7,604.81 -559.51 5,953,330.36 558,074.31 0.00 7,604.81 10,200.00 89.26 0.02 3,693.01 3,584.01 7,704.80 -559.47 5,953,430.34 558,073.57 0.00 7,704.80 10,276.68 89.26 0.02 3,694.00 3,585.00 7,781.47 -559.44 5,953,507.00 558,073.00 0.00 7,781.47 1J-164 T9 (wp06) 10,300.00 88.56 0.01 3,694.44 3,585.44 7,804.79 -559.43 5,953,530.31 558,072.83 2.99 7,804.79 10,360.47 86.75 359.99 3,696.92 3,587.92 7,865.21 -559.44 5,953,590.72 558,072.35 3.00 7,865.21 10,400.00 86.75 359.99 3,699.16 3,590.16 7,904.67 -559.44 5,953,630.18 558,072.04 0.00 7,904.67 10,500.00 86.75 359.99 3,704.84 3,595.84 8,004.51 -559.47 5,953,730.01 558,071.24 0.00 8,004.51 10,600.00 86.75 359.99 3,710.51 3,601.51 8,104.35 -559.49 5,953,829.83 558,070.43 0.00 8,104.35 10,700.00 86.75 359.99 3,716.18 3,607.18 8,204.19 -559.51 5,953,929.66 558,069.63 0.00 8,204.19 10,800.00 86.75 359.99 3,721.86 3,612.86 8,304.03 -559.54 5,954,029.49 558,068.83 0.00 8,304.03 10,900.00 86.75 359.99 3,727.53 3,618.53 8,403.87 -559.56 5,954,129.31 558,068.03 0.00 8,403.87 11,000.00 86.75 359.99 3,733.21 3,624.21 8,503.71 -559.58 5,954,229.14 558,067.23 0.00 8,503.71 11,100.00 86.75 359.99 3,738.88 3,629.88 8,603.54 -559.61 5,954,328.96 558,066.43 0.00 8,603.54 11,200.00 86.75 359.99 3,744.55 3,635.55 8,703.38 -559.63 5,954,428.79 558,065.63 0.00 8,703.38 11,278.35 86.75 359.99 3,749.00 3,640.00 8,781.60 -559.65 5,954,507.00 558,065.00 0.00 8,781.60 1 J-164 T10 (wp06) 11,300.00 87.18 0.01 3,750.15 3,641.15 8,803.23 -559.65 5,954,528.62 558,064.83 2.00 8,803.23 11,306.03 87.30 0.02 3,750.44 3,641.44 8,809.25 -559.65 5,954,534.64 558,064.79 2.00 8,809.25 11,400.00 87.30 0.02 3,754.86 3,645.86 8,903.12 -559.62 5,954,628.50 558,064.08 0.00 8,903.12 11,500.00 87.30 0.02 3,759.57 3,650.57 9,003.00 -559.58 5,954,728.37 558,063.34 0.00 9,003.00 11,600.00 87.30 0.02 3,764.29 3,655.29 9,102.89 -559.55 5,954,828.25 558,062.59 0.00 9,102.89 11,678.85 87.30 0.02 3,768.00 3,659.00 9,181.65 -559.53 5,954,907.00 558,062.00 0.00 9,181.65 BHL @ 541 ft FSL & 2212ft FWL - Sec 23 - T11 N - III OE, 11 679f MD, 3678ft TVD - 41/2" -1J-164 Toe (wp06) 9/13/2005 10:48:44AM Page 8 of 10 COMPASS 2003.11 Build 48 Geologic Targets 1J-164 0 t►-' C©n©cOP'hilirps Halliburton Company Planning Report Geographic NpLLIBURTON Target Name +N/ -S - Northing Easting Alaska - Shape Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-164 (1-6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81') @ 109OOft (D141 (28GL + 81`RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.00ft (13141 (28GL+ 81'RF)) $ire: Kuparuk 1 J Pad North Reference: True Well: Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 Design 1J-164 (wp06) 3,446.00 Geologic Targets 1J-164 Measured Vertical TVD Target Name +N/ -S +E/ -w Northing Easting (ft) - Shape ft ft (ft) (ft) 3,698.88 1J-164 T2 (A2 -Landing) (wp06) 3,262.19 -559.87 5,948,988.28 558,107.80 - Point 3,768.00 4-1/2 6-3/4 3,689.00 1J-164 T8 (wp06) 7,381.42 -559.56 5,953,107.00 558,076.00 - Point 3,446.00 1J-164 T7 (Dtop) (wp06) 1,780.73 -561.21 5,947,507.00 558,118.00 - Point 3,672.70 1J-164 T3 (Peak 1)(wp06) 4,111.57 -561.10 5,949,837.55 558,099.94 - Point 3,706.00 1J-164 T6 (wp06) 6,081.27 -560.69 5,951,807.00 558,085.00 - Point 3,693.44 1J-164 T5 (Peak 2)(wp06) 5,810.62 -563.58 5,951,536.37 558,084.22 - Point 3,707.00 1J-164 T7 (wp06) 6,481.32 -560.58 5,952,207.00 558,082.00 - Point 3,768.00 1J-164 Toe (wp06) 9,181.65 -559.53 5,954,907.00 558,062.00 - Point 3,749.00 1J-164 T10 (wp06) 8,781.60 -559.65 5,954,507.00 558,065.00 - Point 3,694.00 1J-164 T9 (wp06) 7,781.47 -559.44 5,953,507.00 558,073.00 - Point 3,704.41 1J-164 T4 (Trough 1)(wp06) 4,960.95 -562.34 5,950,686.81 558,092.08 - Point .Prognosed °iCasing Points Measured Vertical CpMg Ho% Depth - Depth Dir Dhwww (ft) (ft) 2,324.56 2,203.00 10-3/4 13-1/2 5,456.58 3,670.00 7-5/8 9-7/8 11,678.84 3,768.00 4-1/2 6-3/4 9113/2005 10:48:44AM Page 9 of 10 COMPASS 2003.11 Build 48 OR161NAL Prognosed Formation intersection Points 0 v"0 +ConotoPhillips Halliburton Company Planning Report Geographic HALLISUATON Vertical - OnlUi Ser aska Inclination Alvlas: CRY Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: ' Well Plan 1J-164 (1-6) Company: , ConocoPhillips Alaska (Kuparuk) TVD Reference: IJ-164 (28'+81) @ 109.00ft (D141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference: IJ-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Site: Kuparuk lJ Pad North Reference: True Well: Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 327.04 -12.37 Design: 1J-164 (wp06) 26.24 314.23 Prognosed Formation intersection Points Measured Vertical Depth Inclination Azimuth Depth +Nl-E +El -W (ft) (ft) (ft) 1,593.05 23.79 343.04 1,543.00 285.84 4.64 Base of Permafrost 1,703.47 24.02 332.14 1,644.00 327.04 -12.37 T3 2,025.77 26.24 314.23 1,935.00 431.61 -102.07 K15 2,324.56 26.24 314.23 2,203.00 523.73 -196.72 T3 + 550 (CSG PT) 3,162.82 41.39 339.41 2,922.00 863.85 -442.31 Ugnu C 3,434.03 50.80 346.95 3,110.00 1,050.71 -497.73 Ugnu B 3,497.27 53.05 348.41 3,149.00 1,099.34 -508.34 Ugnu A 3,747.36 62.11 353.45 3,283.00 1,307.57 -541.10 K-13 4,250.33 77.00 0.07 3,446.00 1,780.73 -561.21 West Sak D (77°) 4,445.93 77.00 0.07 3,490.00 1,971.31 -561.00 West Sak C 4,598.53 80.00 0.07 3,521.00 2,120.70 -560.83 West Sak B (80°) 4,811.60 80.00 0.07 3,558.00 2,330.53 -560.59 West Sak A4 5,064.99 80.00 0.07 3,602.00 2,580.07 -560.31 West Sak A3 5,456.58 80.00 0.07 3,670.00 2,965.72 -559.87 West Sak A2 9/13/200510:48:44AM Page 10 of 10 COMPASS 2003.11 Build 48 n ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-164 Anticollision Summary 13 September, 2005 HALLIBUR'TON Sperry Drilling Services SURVEY PROGRAM Date: 20050943M.I[W.00 Va0d>red: Yrs Verdes Depth Fmm Depth To Survey/Plan Tod 20.01) 0M.00 1J-164(wp06) CB -GYRO -SS BW.W 11678.85 1J-164(wp06) MWD+IFR-AK-CAZSC Plan 1J-158 (M3) Plan 1J-180 (M2) 300, Plan 1J-156 (M4)N 1J-162 240 Plan 1J-166 (1-5) 0 ANT -COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 28.00 Toll 678.85 Maximum Range:1080.3062005376 Reference: Plan: 1.0-164(wp06) Plan 1J-111 (M12) 60 Plan 1J-115 (L9) 1 P15n 1J-101 (L7)1 IPlan 1J-118 (L10)I NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-164 (1-6) Ground Level: 81.00 ,N/ -S +EJ -W Northing Easting Latittude Longitude 0.00 0.00 5945730.87 558693.02 70`15'44.408N 149'31'31.BTW 300 Plan 1J-15" �i 01 ��1► P�►.���i of �y '/ I ; `' �Ih iia 0' :,!a��� AWAo;, if,c` A •�1`c ems, :��i %�WSP From Colour To MD ,150` -210 250 500 - z WSP-02 WSP-15 � 750 Plan 1J-168 1000 WSP-04 50 W8P-20 180 Plan 1J-12 1250 1600 Plan 1J--170 (lA) Plan 1J-159 (M7) 1500 - 1750 1750 2000 Travelling Cylinder Azimuth (TFO+AZI) 101 Vs Centre to Centre Separation 1100 ft/int 2000 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 REFERENCE INFORMATION 8000 9000 Co-ordinate (N/E) Reference: Well Plan 1.1-164(16), True North 9000 10000 Vertical (TVD) Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL+81'RF)) 10000 11000 Section (VS) Reference: Slot -(O.00N, O.00E) 11000 12000 Measured Depth Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL+81'RF)) Calculation Method: Minimum Curvature 240 330 20 ConocoPhillips Alaska (Kuparuk) Engineering Slot West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Tmv. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 60 120 2 1J-166 210 150 90 SECTION DETAILS Sec MD Inc Azi TVD +N/ -S +E/ -W DLeg TFace VSec Target 1 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 3 833.33 10.00 8.00 831.64 28.73 4.04 3.00 8.00 28.73 4 1167.56 20.00 5.00 1164.08 114.63 13.08 3.00 354.10 114.63 5 1301.30 25.00 0.00 1277.60 165.71 15.08 4.00 336.73 165.71 6 1415.90 25.00 0.00 1381.47 214.14 15.08 0.00 0.00 214.14 7 1900.79 26.24 314.23 1822.89 393.07 62.47 4.00 -107.46 397.07 8 2653.42 26.24 314.23 2497.98 625.14 -300.90 0.00 0.00 625.14 9 4150.33 77.00 0.07 3423.50 1683.29 561.32 4.00 53.92 1683.29 10 4250.33 77.00 0.07 3446.00 1780.73 561.21 0.00 0.00 1780.73 1J-164 T1 (Dtop) (wp06) 11 4483.53 77.00 0.07 3498.46 2007.95 560.95 0.00 0.00 2007.95 12 4583.67 80.00 0.07 3518.42 2106.07 560.84 3.00 0.00 2106.07 13 5497.67 80.00 0.07 3617.13 3006.16 559.82 0.00 0.00 3006.18 14 5754.95 90.29 359.92 3698.88 3262.19 559.87 4.00 -0.83 3262.19 IJ -164 T2 (A2 -Landing) (wp 15 6094.95 93.69 359.92 3687.07 3601.93 -560.36 1.00 0.00 3601.93 16 6144.95 93.69 359.92 3683.86 3651.83 560.43 0.00 0.00 3651.83 17 6604.95 89.09 359.92 3672.70 4111.57 -561.10 1.00 180.00 4111.57 IJ -164 T3 (Peak 1)(wp06) 18 6964.95 87.29 359.92 3684.07 4471.38 561.63 0.50 180.00 4471.38 19 7094.95 87.29 359.92 3690.22 4601.23 561.82 0.00 0.00 4601.23 20 7454.95 88.19 359.92 3704.41 4960.95 562.34 0.25 0.00 4960.95 1.1-164 T4 (Trough 1)(wp06) 21 7794.95 92.44 359.92 3702.55 5300.86 562.84 1.25 0.00 5300.86 22 7964.95 92.44 359.92 3695.31 5470.71 -563.08 0.00 0.00 5470.71 23 8304.95 88.19 359.92 3693.44 5810.62 563.58 1.25 -180.00 5810.62 IJ -164 T5 (Peak 2)(wp06) 24 8366.75 87.23 0.703695 .91 5872.38 -563.25 2.00 140.68 5872.38 25 8575.90 87.23 0.70 3706.00 6081.27 -560.69 0.00 0.00 6081.27 1J-164 T6 (wp06) 26 8748.76 90.58 359.83 3709.30 6254.07 -559.90 2.00 -14.62 6254.07 27 8976.02 90.58 359.83 3707.00 6481.32 -560.58 0.00 0.00 6481.32 1J-164 T7 (wp06) 28 9044.51 93.25 0.44 3704.71 6549.76 560.42 4.00 12.84 6549.76 29 9266.61 93.25 0." 3692.12 6771.50 558.72 0.00 0.00 6771.50 30 9376.60 90.00 359.87 3689.00 6881.43 558.43 3.00 -110.08 6881.43 31 9876.60 90.00 359.87 3689.00 7781.42 559.56 0.00 0.00 7381.42 1J-164 T8 (wp06) 32 9901.76 89.26 0.02 3689.16 7406.58 559.58 3.00 168.41 7406.58 33 10276.68 89.26 0.02 3694.00 7781.47 559.44 0.00 0.00 7781.47 1J-164 T9 (wp06) 34 10360.47 86.75 359.99 3696.92 7865.21 559.44 3.00 -179.21 7865.21 35 11278.35 86.75 359.99 3749.00 8781.60 559.65 0.00 0.00 8781.60 1J-164 T10 (wp06) 3611306.03 87.30 0.02 3750.44 8809.25 559.65 2.00 3.23 8809.25 37 11678.85 87.30 0.02 3768.00 9181.65 559.53 0.00 0.00 9181.65 1J-164 Toe (wp06) Reference 1J-164 (wp06) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,080.31ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 9/1312005 From ` To jft} (ft) Survey (Wellbore) Tool Name Description 28.00 0.00 1J-164 (wp06) (1J-164) CB -GYRO -SS Camera based gyro single shot 800.00 11,678.85 1J-164 (wp06) (1J-164) 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 9/132005 11:04:57AM Page 3 of 5 COMPASS 2003.11 Build 48 oRie1�vn, t- Halliburton Company HALLIBURTON ConocoMil11p5 Anticollision Report Alaska Sperry Drilling Services Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-164 (1-6) Project: Kuparuk River Unit TVD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Reference Site: Kuparuk 1J Pad MD Reference: IJ -164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) Site Error: 0.00ft North Reference: True Reference Well: Plan 1J-164 (1-6) Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1J-164 Database: EDM 2003.11 Single User Db Reference Design: ; 1 J-164 (wp06) Offset TVD Reference: Offset Datum Reference 1J-164 (wp06) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,080.31ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 9/1312005 From ` To jft} (ft) Survey (Wellbore) Tool Name Description 28.00 0.00 1J-164 (wp06) (1J-164) CB -GYRO -SS Camera based gyro single shot 800.00 11,678.85 1J-164 (wp06) (1J-164) 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 9/132005 11:04:57AM Page 3 of 5 COMPASS 2003.11 Build 48 oRie1�vn, t- ConocoPPhillips Aiaska Company: ConocoPhillips Alaska (Kuparuk) ct: Kuparuk River Unit once Site: Kuparuk 1J Pad Error: 0.00ft enoe Well: Plan 1J-164 (L6) Error: 0.00ft -once Wellbore 1J-164 -once Design: ; 1J-164 (wp06) Halliburton Company Anticollision Report HALLIBURTON Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-164 (1-6) TVD Reference: 1J-164 (28'+81') @ 109.00ft (13141 (28GL + 81'RF)) MD, Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL+ 81'RF)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset ND Reference:Offset 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 - Wetlbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1J-03 - 1J-03 - 1J-03 142.88 150.00 212.44 2.52 209.92 Pass - Major Risk 1J-09 - 1J-09 - 1J-09 293.93 300.00 240.08 5.37 234.71 Pass - Major Risk 1J-10 - 1J-10 - 11-10 800.74 800.00 74.24 14.96 59.28 Pass - Major Risk Plan 1J-101 (L7) - Plan 1J-1-7 A Lat - Plan 1J -L7 A 1,663.63 1,600.00 96.87 29.63 67.24 Pass - Major Risk Plan 1J-102 (M8) - 1J-102 - 1J-102 (wp03) 1,359.96 1,250.00 270.16 24.94 245.22 Pass - Major Risk Plan 1J-102 (M8) - 1J-102 L1 - 1J-102 L1 (wp03) 1,359.96 1,250.00 270.16 24.85 245.31 Pass - Major Risk Plan 1J-102 (M8) - 1J-102 L2 - 1J-102 L2 (wp03) 1,359.96 1,250.00 270.16 24.85 245.31 Pass - Major Risk Plan 1J-103 (M9) - Plan 1J -M9 - Plan 1J -M9 1,145.59 1,050.00 308.66 20.39 288.27 Pass - Major Risk Plan 1J-105 (M10) - Plan 1J -M10 Lat A - Plan 1J -M 906.86 850.00 286.93 16.71 270.21 Pass - Major Risk Plan 1J-107 (Ml 1) - Plan 1J -M11 Lat A - Plan 1J -M 350.99 350.00 247.58 6.75 240.83 Pass - Major Risk Plan 1J-109 (M13) - Plan 1J -M13 Lat A - Plan 1J -M 300.99 300.00 202.28 5.81 196.47 Pass - Major Risk Plan 1J-111 (M12) - Plan 1J -M12 Lat A - Plan 1J -M 350.99 350.00 177.06 6.75 170.31 Pass - Major Risk Plan 1J-115 (L9) - Plan 1J -L9 Lat A - Plan 1J -L9 L 604.83 600.00 148.12 11.49 136.64 Pass - Major Risk Plan 1 JA 18 (1-10) - Plan IJ -LIG Lat A - Plan IJ -LI 450.99 450.00 151.70 8.62 143.08 Pass - Major Risk Plan 1J-12 - Plan 1J-12 (K2 Prelim) - 1J-12 (K2 Pr 1,200.00 1,200.00 109.81 24.21 85.61 Pass - Major Risk Plan 1J-120 (L11) - Plan 1 J -L11 Lat A - Plan 1J -L1 450.99 450.00 167.06 8.62 158.44 Pass - Major Risk Plan 1J-122 (L12) - Plan 1 J -L12 Lat A - Plan 1 J -L1 350.99 350.00 189.61 6.75 182.87 Pass - Major Risk Plan 1J-124 (L13) - Plan 1J -L13 Lat A - Plan 1J -L1 300.99 300.00 217.27 5.81 211.46 Pass - Major Risk Plan 1J-152 (105) - 1J-152 - 1J-152 (wp04) 349.99 350.00 280.44 7.58 272.86 Pass - Major Risk Plan 1J-152 (M5) - 1J-152 L1 - 1J-152 L1 (wp04) 349.99 350.00 280.44 7.58 272.86 Pass - Major Risk Plan 1J-152 (M5) - 1J-152 L2 - 1J-152 L2 (wp04) 349.99 350.00 280.44 7.58 272.86 Pass - Major Risk Plan 1J-154 - 1J-154 - 1J-154 (wp06) 2,725.94 2,650.00 108.62 54.56 54.06 Pass - Major Risk Plan 1J-154 - 1J-154 L1 - 1J-154 L1 (wp06) 2,725.94 2,650.00 108.62 54.57 54.05 Pass - Major Risk Plan 1J-154 - 1J-154 L2 - 1J-154 L2 (wp06) 2,725.94 2,650.00 108.62 54.57 54.05 Pass - Major Risk Plan 1J-156 (M4) - Plan 1J -M4 A Lat - Plan 1J -M4 921.39 900.00 166.80 17.31 149.49 Pass - Major Risk Plan 1J-158 (103) - 1J -M3 A Lateral - 1J -M3 A Late 350.92 350.00 140.86 6.59 134.27 Pass - Major Risk Plan 1J-159 (M7) - 1J-159 - 1J-159 (wp03) 1,163.84 1,150.00 40.92 21.02 19.90 Pass - Major Risk Plan 1J-159 (M7) - 1J-159 L1 - 1J-159 L1 (wp03) 1,163.84 1,150.00 40.92 21.02 19.90 Pass - Major Risk Plan 1J-159 (M7) - 1J-159 L2 - 1J-159 L2 (wp03) 1,163.84 1,150.00 40.92 21.02 19.90 Pass - Major Risk Plan 1J-160 (M2) - Plan 1J -M2 Lat A - Plan 1J -M2 350.92 350.00 100.62 6.76 93.86 Pass - Major Risk Plan 1J-162 (M1) - 1J-162 - 1J-162 (wp03.1-North 350.92 350.00 40.62 7.44 33.18 Pass - Major Risk Plan 1J-162 (M1) - 1J-162 L1 - 1J-162 L1 (wp3.1) 350.92 350.00 40.62 7.34 33.28 Pass - Major Risk Plan 1J-162 (M1) - 1J-162 L2 - 1J-162 L2 (wp3.1) 350.92 350.00 40.62 7.34 33.28 Pass - Major Risk Plan 1J-166 (1-5) - 1J-166 - 1J-166 (wp03) 549.83 550.00 40.01 11.70 28.31 Pass - Major Risk Plan 1J-166 (L5) - 1J-166 L1 - 1J-166 L1 (wp03) 549.83 550.00 40.01 10.62 29.39 Pass - Major Risk Plan 1J-166 (1-5) - 1J-166 L2 - 1J-166 L2 (wp03) 549.83 550.00 40.01 10.62 29.39 Pass - Major Risk Plan 1J-168 - 1J-168 - 1J-168 (wp10 - Revised 8/ 399.85 400.00 82.19 8.66 73.53 Pass - Major Risk Plan 1J-168 - 1J-168 - 1J-168 Rig 399.85 400.00 82.19 8.66 73.53 Pass - Major Risk Plan 1J-168 - 1J-168 L1 - 1J-168 L1 Rig 399.85 400.00 82.20 8.66 73.54 Pass - Major Risk Plan 1J-168 - 1J-168 L1 - 1J-168 L1(wp10 - Revis 399.85 400.00 82.20 8.66 73.54 Pass - Major Risk Plan 1J-168 - 1J-168 L2 - 1J-168 L2 (wp10 - Revis 399.85 400.00 82.20 8.66 73.54 Pass - Major Risk Plan 1J-168 - 1J-168 L2 - 1J-168 L2 Rig 399.85 400.00 82.19 8.66 73.53 Pass - Major Risk Plan 1J-170 (1-4) - Plan 1J -L4 LatA - Plan 1J -L4 La 500.00 500.00 120.96 9.53 111.44 Pass - Major Risk Plan 1J-174 (Q1) - Plan 1J -Q1 B Lat - Plan 1J -Q1 250.99 250.00 200.71 4.87 195.85 Pass - Major Risk Plan 1J-176 (Q2) - Plan 1J -Q2 B Lat - Plan 1J -Q2 300.99 300.00 240.84 5.80 235.04 Pass - Major Risk Plan 1J-50 (Ugnu Disposal) - Plan 1J-UgnuDispos 350.99 350.00 320.43 6.75 313.68 Pass - Major Risk WSP-02 - WSP-02 - WSP-02 1,264.94 1,250.00 138.88 25.88 112.99 Pass - Major Risk WSP-03 - WSP-03 - WSP-03 1,119.51 1,100.00 153.23 27.00 126.23 Pass - Major Risk WSP-04 - WSP-04 - WSP-04 995.66 1,000.00 162.81 20.60 142.21 Pass - Major Risk WSP-05 - WSP-05 - WSP-05 834.70 850.00 191.15 22.67 168.48 Pass - Major Risk WSP-06 - WSP-06 - WSP-06 633.44 650.00 222.60 16.90 205.70 Pass - Major Risk WSP-07 - WSP-07 - WSP-07 629.85 650.00 256.30 19.27 237.03 Pass - Major Risk WSP-15 - WSP-15 - WSP-15 1,422.40 1,400.00 118.08 32.42 85.66 Pass - Mamor Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/132005 11:04:57AM Page 4 of 5 COMPASS 2003.11 Build 48 Halliburton Company MALLIBURTCIIV Anticollision Report Sperry Griilltny Ser Ac" Local Co-ordinate Reference: Well Plan 1J-164 (L6) ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: = Kuparuk 1J Pad Site Error: 0.00ft Reference Well: Plan 1J-164 (L6) Well Error: 0.00ft Reference Wellbore 1J-164 Reference Destgn: 1J-164 (wp06) Halliburton Company MALLIBURTCIIV Anticollision Report Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance ° Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad WSP-1 S - WSP-1 S - WSP-1 S 1,535.17 1,500.00 109.29 64.35 44.94 Pass - Major Risk WSP-20 - WSP-20 - WSP-20 652.49 650.00 41.42 16.37 25.05 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/13!2005 11:04:57AM Page 5 of 5 COMPASS 2003.11 Build 48 ORIGINAL Sperry Griilltny Ser Ac" Local Co-ordinate Reference: Well Plan 1J-164 (L6) TVD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) MD Reference: 1J-164 (28'+81') @ 109.00ft (D141 (28GL + 81'RF)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors, are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset ND Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance ° Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad WSP-1 S - WSP-1 S - WSP-1 S 1,535.17 1,500.00 109.29 64.35 44.94 Pass - Major Risk WSP-20 - WSP-20 - WSP-20 652.49 650.00 41.42 16.37 25.05 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/13!2005 11:04:57AM Page 5 of 5 COMPASS 2003.11 Build 48 ORIGINAL -16*Dri (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate - Control drill, Reduced pump rates, Reduced Lost Circulation Low drilling fluid temperatures, Additions of Gas Hydrates Low Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted Stuck Pipe Low sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Gravels Low Increase mud weight, use weighted Lost Circulation Low 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 Pressure 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 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy 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, backreamin 1J-164 Drilling Hazardsy.doo prepared by Shanene Clo C/oninger ORIGINAL9/21/2005 1:17 PM Rig: Doyon 141 Location: West Sak Client: CPAI. Revision Date: 9/14/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com at Surface Previous Csg. < 20", 91.5# casing at 80' M D < Base of Permafrost at 1,593' MD (1,543' TVD) < Top of Tail at 1,718' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,318' M D (2,197' TVD) Mark of Schlumberger 0016FIIC�ADE:Prelriffminary Job Dessl� - ,A03/4 urfape Preliminary Job Design based on limited input data. For estimate purposes only. Schlumberger 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 1,718' MD. Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x (11593'- 80') x 3.50 (250% excess) = 1926.1 ft3 0.3637 ft3/ft x (1718'- 1593') x 1.35 (35% excess) = 61.3 ft3 109.2 ft3 + 1926.1 ft3+ 61.3 ft3 = 2096.6 ft3 2096.6 ft3/ 4.45 ft3/sk = 471.1 sks Round up to 480 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637 ft3/ft x (2318'- 1718') x 1.35 (35% excess) = 294.6 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 294.6 ft3 +43.2 ft3 = 337.8 ft3 337.8 ft3/ 2.52 ft3/sk = 134 sks Round up to 140 sks BHST = 47°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry 7 380 54.3 89.3 Tail Slurry 6 63 10.5 99.8 Drop Top Plug 10.0 109.8 Displacement 7 200 28.6 138.4 Slow Rate 3 15 5.0 143.4 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 1 per joint across zones of interest for proper cement placement. Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 9/15/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Email: cakwukwaegbu@slb.com Previous Csg. < 10 3/4", 45.5# casing at 2,318' MD < Top of Tail at 2,663' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 5,419' MD (3,600' TVD) Mark of Schlumberger O�CA�DEem;;Preliminary Job Deslg 7625" Intermediate Casi.. 3 Preliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 2756' shoe tack. Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.2148 ft3/ft x 2756'x 1.40 (40% excess) = 828.8 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 828.8 ft3 +20.6 ft3 = 849.4 ft3 849.4 ft3/ 2.26 ft3/sk = 375.8 sks Round up to 380 sks BHST = 83°F, Estimated BHCT = 72°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 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Tail Slurry 5 153 30.6 65.6 Drop Top Plugl I 1 10.0 1 75.6 Displacementl 6 1 225 1 37.5 1 113.1 Slow Ratel 3 1 20 1 6.7 1 119.8 MUD REMOVAL Recommended Mud Properties: 9.8 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 1 per joint across zones of interest for proper cement placement. CD rn Ky m 0 ter;er w $ e CAMCO 3.562" "DB" nipple. 0 Insulated Conductor n Casing, 20", 94#, K55 x 0 34", 0.312" WT @ i$ x 80' MD a + @ 5,419' MD / 3,670' TVD @ 80 degrees TD 9-58" hole N CD rn Ky m ter;er w $ e CAMCO 3.562" "DB" nipple. g' o .- V J W below "B" window 10-3/4', 68#, L-80, BTC, R3 Op @ 2,318' MD / 2,193' TVD @ 26.24 degrees TD 13-3/8" hole Top of Ugnu C 3,163' MD / 2,922' TVD Lateral Entry Module 92 (LEM), Baker, with seal bore and ZXP packer above. Wellhead / Tubing Head / Tree, 10-3/4" x 4-'/:", 5,000 ksi __— Tubing String: 4-1/2", 12.6 #, L-80, IBTM Top of West Sak B * 10 `yt 3,434' DID / 3,110' TVD — — Lateral Entry Module #I (LEM), Baker, with seal bore and ZXP packer above. Top of West Sak A @ 10 3,497'N1D/3,149'TVD (1) 3.875" DB nipple set @ 500' _ (1) Gas Lift Mandrel, CAMCO4-1/2" x I" Model KBG- 2, one (1) set at 67 deg, X,XX V MD, X,XXX TVD. (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG- 2, one (1) set at 68 deg, X,XXX' MD, X,XXX' TVD. (1) Sliding Sleeve, with 3.812" nipple, one (1) joint above _ packer. X,XXX MD, X,XXV TVD 164 L2 "D" Sand Window @ 4,546' MD / 3,519 TVD 77 degrees "D" Liner, 4-1/2", 12.8#, L80, BTCM, R3 (0.125" x 2.5" slots, 32 per foot, 5.9% open area) IF 164 Ll"B" Sand Window @ 4,239' MD / 3,446' TVD 77 degrees "B" Liner, 4-1/2", 12.8#, L80, BTCM, R3 (0.125" x 2.5" slots, 32 per foot, 5.9% open area) BTCM, R3 % slotted and 1/2 blank, constrictors for isolation 1E-105 FINAL: ASP NAD 27 Ea i p: 550,300 ASP NAD 27 Nrn Wnp. 5,959,980 Ped Eleved"n'. 666 AMSI. Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 94.1' AMSL 9 IJ -RA L2. 6-3/4" D sand lateral _ TD 11,649 MD / 3,570' TVD Angle 87 degrees IJ -164 Ll: Tubing, 4-%" IBTM, from LEM to A2 Liner, with seal stem and $ e CAMCO 3.562" "DB" nipple. g' o Seal bore and ZXP packer for A2 liner g W below "B" window i$ x 7-5/8',40#, L-80, BTCM, R3 Csg a + @ 5,419' MD / 3,670' TVD @ 80 degrees TD 9-58" hole IF 164 Ll"B" Sand Window @ 4,239' MD / 3,446' TVD 77 degrees "B" Liner, 4-1/2", 12.8#, L80, BTCM, R3 (0.125" x 2.5" slots, 32 per foot, 5.9% open area) BTCM, R3 % slotted and 1/2 blank, constrictors for isolation 1E-105 FINAL: ASP NAD 27 Ea i p: 550,300 ASP NAD 27 Nrn Wnp. 5,959,980 Ped Eleved"n'. 666 AMSI. Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 94.1' AMSL 9 IJ -RA L2. 6-3/4" D sand lateral _ TD 11,649 MD / 3,570' TVD Angle 87 degrees IJ -164 Ll: 6-3/4" "B" sand lateral TD 11,655' MD / 3,619' TVD Angle 87 degrees I1-164: --o=moi teral TD 1 1,667' MD / 3,793'T 1 Angle 87 degrees ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-164 (1-6) 1J-164 1J-164 (wp06) Sperry -Sun 1/4 Mile Proximity Summary 13 September, 2005 HALLIBURTON • 0 1 T t M ths to True North zimu ag, etic North: 25.06° -4620 -3960 West( -)/East(+) 03ZU T"') ConocoPhillips Alaska W Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-164 (1-6) Wellbore: 1J-164 Plan: 1J-164 (wp06) 1D-131, 1D-131, 1D-131 V2 Plan 1J-168, 1J-168 L1, 1J-168 L1 Rig VO Plan 1J-168, 1J-168, 1J-168 Rig VO CASING DETAILS No TVD MD Name Size 1 2203.00 2324.56 10 314" 10-314 2 3670.00 5456.58 7 6/8" 7-518 3 3768.00 11678.84 41/2" 4-112 1 J-09, 1 J-09, 1 J-09 V7 1J-164 (1/4 Mile Radius) - Toe 1J-164 (1/4 Mile Radius) - Heel 13D- View #2 1J-164 with existing wells Looking from South East HALLIBURTON Anticollision Report for Kuparuk 1J Pad - Plan 1J-164 (1-6) - 1J-164 - 1J-164 (wp06) Closest Approach 3D Proximity Scan on Current Survey Data (Grid North Reference) Scan Radius is ft Comparison Well Name - Wellbore Name - Design ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit 3 Reference Well Kuparuk 1 D Pad Comparison Well 1 D-07 - 1 D-07 - 1 D-07 Proximity 1D-131 - 1D-131 - 113-131 Vertical Kuparuk 1J Pad Vertical 1J-03 - 1J-03 - 1 J-03 (�� Relative `• 1,1-09 - 1,1-09 - 1 J-09 Depth Depth Depth 1J-10 - 1J-10 - 1J-10 +E/ -W Plan 1J-168 - 1J-168 -1J-168 Rig North Plan 1J-168 - 1J-168 L1 - 1J-168 L1 Rig ;R (ft) (ft) WSP-02 - WSP-02 - WSP-02 (ft) WSP-03 - WSP-03 - WSP-03 �-�+ ( 11,225.47 3,746.00 WSP-04 - WSP-04 - WSP-04 4,915.96 WSP-05 - WSP-05 - WSP-05 -334.12 WSP-06 - WSP-06 - WSP-06 221.82 WSP-07 - WSP-07 - WSP-07 WSP-15 - WSP-15 - WSP-15 WSP-1S - WSP-1S - WSP-1S WSP-20 - WSP-20 - WSP-20 ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit 3 Reference Well Comparison Well Proximity Measured Vertical Measured Vertical Relative Relative Depth Depth Depth Depth +N/ -S +E/ -W Distance North (ft) (ft) (ft) (ft) (ft) (ft) (ft) Direction 11,225.47 3,746.00 6,400.00 4,915.96 10,425.29 -334.12 2,073.09 221.82 11,225.47 3,746.00 6,342.08 3,994.89 9,907.28 -469.41 1,207.83 1 212.34 4,250.33 3,446.00 2,378.97 2,020.00 613.94 932.54 2,371.96 60.75 5,618.69 3,697.26 4,979.12 3,557.92 3,121.07 -927.65 393.48 343.48 4,250.33 3,446.00 3,180.17 2,324.34 766.49 -1,522.00 1,791.62 293.91 4,250.33 3,446.00 1,844.35 1,522.14 -337.66 -694.39 2,864.70 253.06 4,250.33 3,446.00 1,844.35 1,522.14 -337.66 -694.39 2,864.70 253.06 4,250.33 3,446.00 3,621.50 3,573.73 324.23 -155.34 1,517.38 282.22 4,250.33 3,446.00 3,154.43 3,100.50 242.99 611.08 1,964.25 92.79 4,250.33 3,446.00 3,637.20 3,603.41 287.69 293.44 1,727.54 27.39 4,250.33 3,446.00 3,832.88 3,758.23 278.36 -200.13 1,576.38 299.50 4,250.33 3,446.00 3,651.90 3,456.81 -33.78 -657.73 1,817.11 274.41 4,250.33 3,446.00 3,509.68 3,445.93 -146.12 -187.05 1,962.84 259.00 4,250.33 3,446.00 3,706.14 3,610.76 720.29 390.93 1,434.66 12.52 4,250.33 3,446.00 3,499.33 3,490.77 323.45 118.27 1,608.53 0.00 4,250.33 3,446.00 3,632.80 3,564.66 235.89 283.50 1,764.69 52.49 13 September, 2005 - 12:21 Page 4 of 4 COMPASS Well Name Hole I Size Csg. I Size Csg. Depth LOT Date I Cemented Cement Description TVD MD 1D-131 9.875" 7.625" 3,995' 6,457' 14.7 ppg 7/12/1998 TEST LINES TO 3500 PSI. PUMP 20 BBLS PREFLUSH, 50 BBLS 10.5 SPACER, 137 BBLS 10.5 CMT, 63 BBLS 15.8 CMT, DROP PLUG, PUMP 5 BBLS CMT, 25 BBLS WASH WATER AND DISPLACED W/RIG PUMPS AT 8 BPM. RU Schlumberger. Run USIT log f/ 6300' to surface.RD Schlumberger. IJ -09 9.875" 7.625" 3,949' 5,639' 15.4 ppg 3/15/2001 PJSM Pump 10 bbls CW100 Preflush Test lines to 3500 PSI 10 bbls CWI00 Preflush Drop btm plug 50 bbls 10.5 ppg MudPUSH Mix & pump 514 bbls lead cmt.@ 10.7 ppg Followed by 145 bbls tail cmt. @ 12.0 ppg Drop btm. plug Displace cmt. w/ 10 bbls wash water Continue displacement w/ rig pump to a total of 433.3 bbls mud Did not bump plug Had 313 bbls cmt. returns to surface Had good returns thru out job CIP 2338 hrs. • 0 within 1/4 mile radius 1D-131 Lead to Surf. 6,457' MD LA &a 5,639' MD 3,995' TVD 3,949' TVD within 1/4 mile radius U-09 • 0 Stage Tool @ 2,982' eC7 TOC by bond log @ 600' T` Lead to Surf. 6,457' MD LA &a 5,639' MD 3,995' TVD 3,949' TVD within 1/4 mile radius U-09 • 0 / Y IE—OZ E-28 '. �l 1 —22 40 ftD-127�D 131 10-1 32 �3 y ID -127 1D-07 U-164 'D_13; t I t D�R 38 I' ` I E-31 P8 _ TIE -105P81 1 .- _. j1E 119ID y Area of Review tE-34 \ 09 1�t EE r IL 2a tE—J8 tE-32 U-168 Slotted Liner 12000 IE -35 1 1 L -29i 'I 1J-10 34 1 L-2114 '} i 1 1L-210* 1 8000 7 000 — � 0 IE—I 17L2 PA P-13 O WSP-14 T11 N, R10E, UM T10N, R11 E, UM KRU U-164 Proposed1-Winj , West Sak A2 Sand 2051440 Confidential wells are red SFD 1015/2005 Feet 1 ,999 2,000 3,900 4,099 1112 SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO 1530 62-14/311 700 G ST. DATE ANCHORAGE AK 99501 G y^/� �//► f�7 PAY TO THE ( / l/� t�r �� $ /00 629 ORDER OF s.a,�K— �1 .livS /bB —�p' 8 CHASE Chase Manhattan Bank USA, N.A. Valid Up TO 5000 Dollars r200 W, Clay Center Or., Newark, OE 19111 MEMO -- — — ----- — — L� 1:03110014411:2L8471907927611-1112 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ICk?t I—T_ 16 s PTD# 2-05--1 CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/iniect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 0jodyAransmittal_checklist Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-164 Program SER Well bore seg ❑ PTD#: 2051440 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - - - - - Surface location and top productive interval in ADL 025661;_ TD in ADL 025650._ - - - - - _ _ _ _ _ - - - - - - _ _ 3 Uniquewell_nameandnumber-------------------------------------- Yes-------------------------- --------- --------------------------------- 4 Well located in_a_defined -pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ - KUPARUK RIVER,_WEST SAK OIL- 490150,_g-overned_by Conservation Order No._ 4068 - - - - _ _ _ _ - - - - - _ _ 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 - - - - - - - No restrictions as to well spacing in CO -4068._ _ _ _ _ - - - - - - - _ _ _ _ _ - - - - - - - - - - _ _ - - - - - - _ _ _ _ - - 7 Sufficient acreage available in -drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ _ _ - No restrictions as to well spacing except that no -pay shall be opened in a well closer - - - - - - - _ - _ _ _ - - - - - _ 8 -if deviated, is -wellbore plat_included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ than 50.0 feet to -an external_ property line._ _ _ _ - - - - - _ _ _ _ - - - - - - - _ _ _ _ _ - - - - - - _ _ _ _ - - - _ 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ _ 10 Operator has_appropriate_bondinfQrce--------------- --------- -- - - - - -- Yes--------------------------------------------------------------------------- 11 Permit can be issued without conservation order_ - - - - - - - - - - - - - - - - - - Yes Appr Date 12 Permit can be issued without administrativ_e_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ _ _ SFD 10/5/2005 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and -strata authorized by Injection Order # (put 10# in- comments) -(For_ Yes - - - - - - No, Area Injection Order No._2B - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells_within 1/4 -mile area_of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ KRU 1 D-131_ is 750' pool. _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - _ _ _ _ _ _ _ - _ _ _ _ 16 Pre -produced injector_ duration -of pre production Less than 3 months_ (For service well only) - _ Yes _ Yes Greener, CPAI,_ 1.0/5/2.005: May be pre -produced for 1 month, 17 AC_M_P_ Finding ofConsistency-has been -issued _for _ this project____________________ NA____________________________________________ --________________-------______- Engineering 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 Surface casing_ protects all -known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ All aquifers exempted, 40 CFR_147.102_ (b)_(3)._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _C_MT_vol_ adequate to circulate_on conductor & surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _ _ - - - _ 21 CMT_vol_ adequate to tie -in -long string to surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - - - - - - _ _ _ _ _ _ - - - - - - - - _ - _ _ _ _ _ - - _ - - - _ _ _ _ - - - - - - - - - _ _ _ _ _ - - - - - _ _ _ _ _ _ - - - 22 CMT_will cover all known -productive horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _N_o_ Slotted liner completion planned._ Any hydrocarbons above WS will be cemented._ - - - - - - - - _ _ _ _ _ 23 Casing designs adequate for C,_T, B & permafrost- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ - - - - - _ -- _ - - - - - - _ - - - - - - - - - _ _ _ _ _ - - - - - - 24 Adequate tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ - Yes - - - - - - _ Rig is- equipped -with steel -pits. -No reserve_ pit planned. All waste to -approved annulus -or disposal well._ _ _ - - - - 25 ff a_re-drill, has_a 10-403 for abandonment been approved - _ _ _ _ . _ _ - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - ._ _ - - - - - - - _ - _ _ _ _ - - - - - _ _ _ _ _ - - - - - - - - - - _ - - - - - - - - - - - 26 Adequate wellbore - - - - - - -- - P_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _Proximity_ an performed. Traveling cylinder plot included. _ Gyros- possible. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ _ _ _ _ _ - - - _ _ _ _ _ _ - - - - - - - - _ _ _ _ _ - - - - - - - _ _ _ _ _ _ - - - - - - _ _ _ _ - - - - - - - _ _ _ _ - - - - - - _ Appr Date 28 Drilling fluid_ uiram schematic_& program � a plist a dequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ _ _ _ _ - Maximum expected formation pressure _8.7 EMW. 9.1 _ppg in_9-7/8" hole and 8.6 + in_ WS._ _ - - - - _ - _ _ _ _ _ - TEM 10/5/2005 29 BOPEs,_do they meet_ regulation Yes _ _ Rig employs_5000 wp stack equipped with 1 set of DP rams_a_nd 1 set of casing rams. Meets 25.035 (e)(1)(A)._ 30 BOPE_press rating appropriate; test to_(pu_t psig in comments) _ _ - - - - - - - _ _ _ _ - _Yes _ MASP calculated at - - -psi. 3000 psi_BOP test proposed._ _ _ _ _ _ - - - - - - - ---- --- �.. 31 Choke manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - - Yes - - _ _ _ _ - _ _ _ - - - - - - _ _ _ - - - - - - - _ _ _ _ - - - - - - _ _ _ _ _ - - - - - - - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ _ _ _ _ - - - - - - - _ _ _ _ -------------------------------------------------------- 33 Js presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No - _ _ - - H2S has -not been reported in WS._ Rig -is equipped with sensors -and alarms, - - _ _ - - - - - - - - _ _ _ - - - 34 Mechanical condition of wells within AOR verified (For_ service well only) - - - - - - - - - - - - - - Yes _ - - - _ 2 wells in AOR. _ No issues identified. - - - - - _ . Geology 35 Permit_can beissued w/o hydrogen sulfide measures --------------------------- Yes_ _ - - - - - - _ _ _ - _ _ - - -- - - - - _ _ 36 Data_presented on potential overpressure zones- - - - - - - _ _ _ - _ _ _ _ _ Yes - - - - - - . None expected;_ estimated reservoirpressure is 8.7_ppg EMW. _Mitigation_ strategy discussed in_Drilling _ - _ - - - - Appr Date 37 Seismic analysis of shallQw gas -zones ----------- - - - NA_ _ _ - - - Hazards section. _Gas hydrates may be encountered, mitigation discussed in Drilling Hazards_section._ - - - - _ - _ SFD 10/5/2005 38 Seabed condition survey off -Shore) - - - - - - NA - 39 - Contact name/phone_for_weekly progress_ reports [exploratory only]- - - - - - - - - - - - - - - - N _ A _ - Geologic Engineering P Date: Date Undulating West Sak A -Sand injector. Date g Commissioner: Commissioner: C iss er Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 23 08:52:03 2006 Reel Header Service name.............LISTPE Date .....................06/03/23 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library Tape Header Service name.............LISTPE Date .....................06/03/23 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0004025932 T. GALVIN M. THORTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING U Scientific Technical Services Scientific Technical Services 1J-164 500292327800 ConocoPhillips Alaska, Inc. Sperry Drilling Services 23 -MAR -06 MWD RUN 3 MW0004025932 T. GALVIN M. THORTON 35 11N 10E 1919 2517 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2332.0 7.875 5358.0 a a, - / '�4a REMARKS: • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 2 ALSO INCLUDED ACOUSTIC CALIPER (ACAL). MWD RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) AND AT -BIT INCLINATION (ABI). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 1J-164 WITH API#:50-029-23278-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11400'MD/3745'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. 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 ....... 06/03/23 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 2297.0 11342.5 RPS 2310.0 11349.5 FET 2310.0 11349.5 RPM 2310.0 11349.5 RPD 2310.0 11349.5 RPX 2310.0 11349.5 • i CALA 2320.0 5279.0 ROP 2342.5 11400.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2297.0 5358.0 MWD 3 5358.0 11400.0 $ 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 .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 CALA MWD INCH 4 1 68 4 2 RPD MWD OHMM 4 1 68 8 3 RPM MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 FET MWD HOUR 4 1 68 24 7 GR MWD API 4 1 68 28 8 ROP MWD FT/H 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2297 11400 6848.5 18207 2297 11400 CALA MWD INCH 8.36 12.68 9.62066 5003 2320 5279 RPD MWD OHMM 0.05 2000 32.5074 18080 2310 11349.5 RPM MWD OHMM 0.41 2000 19.5373 18080 2310 11349.5 RPS MWD OHMM 3.22 2000 15.0973 18080 2310 11349.5 RPX MWD OHMM 0.11 1611.15 14.2479 18080 2310 11349.5 FET MWD HOUR 0.2 59.59 1.03569 18080 2310 11349.5 GR MWD API 22.29 123.35 78.0169 18092 2297 11342.5 ROP MWD FT/H 7.32 641.18 189.459 18116 2342.5 11400 First Reading For Entire File.......... 2297 Last Reading For Entire File ........... 11400 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 06/03/23 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 ....... 06/03/23 Maximum Physical Record..65535 File Type................L0 Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 SOFTWARE RAW MWD SURFACE SOFTWARE VERSION: Insite Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 5358.0 DEPTH INCREMENT: .5000 BOTTOM LOG INTERVAL (FT): 5358.0 BIT ROTATING SPEED (RPM): FILE SUMMARY Other MINIMUM ANGLE: VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2297.0 5311.5 FET 2310.0 5304.0 RPX 2310.0 5304.0 RPS 2310.0 5304.0 RPM 2310.0 5304.0 RPD 2310.0 5304.0 CALA 2320.0 5279.0 ROP 2342.5 5358.0 LOG HEADER DATA DATE LOGGED: 06-NOV-05 SOFTWARE 132482 SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5358.0 TOP LOG INTERVAL (FT): 2342.0 BOTTOM LOG INTERVAL (FT): 5358.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Other MINIMUM ANGLE: 24.4 MAXIMUM ANGLE: 81.3 MUD PH: 9.4 M # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 ACAL Acoustic Caliper 143392 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER°S CASING DEPTH (FT): 2332.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 44.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 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 MUD AT MEASURED TEMPERATURE (MT): 2.900 720 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 115.0 INCH MUD FILTRATE AT MT: 3.500 72.0 MUD CAKE AT MT: 3.000 72.0 OHMM 4 1 68 8 3 NEUTRON TOOL RPM MWD020 MATRIX: OHMM 4 1 68 12 MATRIX DENSITY: RPS HOLE CORRECTION (IN): OHMM 4 1 68 16 5 TOOL STANDOFF (IN): MWD020 OHMM EWR FREQUENCY (HZ): 20 6 FET MWD020 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 CALA MWD020 INCH 4 1 68 4 2 RPD MWD020 OHMM 4 1 68 8 3 RPM MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPX MWD020 OHMM 4 1 68 20 6 FET MWD020 HOUR 4 1 68 24 7 GR MWD020 API 4 1 68 28 8 ROP MWD020 FT/H 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2297 5358 3827.5 6123 2297 5358 CALA MWD020 INCH 8.36 12.68 9.62066 5003 2320 5279 RPD MWD020 OHMM 4.06 2000 31.4992 5989 2310 5304 RPM MWD020 OHMM 0.41 126.15 15.3587 5989 2310 5304 RPS MWD020 OHMM 3.67 1217.56 15.2309 5989 2310 5304 RPX MWD020 OHMM 2.2 80.99 13.0295 5989 2310 5304 FET MWD020 HOUR 0.2 52.32 1.16577 5989 2310 5304 GR MWD020 API 22.29 111.65 71.0537 6030 2297 5311.5 ROP MWD020 FT/H 7.32 641.18 174.587 6032 2342.5 5358 First Reading For Entire File.......... 2297 Last Reading For Entire File ........... 5358 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 06/03/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 f • Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 06/03/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 TD DRILLER (FT): 11400.0 FILE SUMMARY 5358.0 VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 5304.5 11349.5 RPD 5304.5 11349.5 FET 5304.5 11349.5 RPM 5304.5 11349.5 RPX 5304.5 11349.5 GR 5312.0 11342.5 ROP 5358.5 11400.0 DGR DUAL GAMMA RAY 087225 LOG HEADER DATA DATE LOGGED: 11-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11400.0 TOP LOG INTERVAL (FT): 5358.0 BOTTOM LOG INTERVAL (FT): 11400.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 81.5 MAXIMUM ANGLE: 94.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5358.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 74.0 MUD PH: .0 MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3): 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 126.0 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 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 5304.5 11400 8352.25 12192 5304.5 11400 RPD MWD030 OHMM 0.05 2000 33.0069 12091 5304.5 11349.5 RPM MWD030 OHMM 3.29 2000 21.607 12091 5304.5 11349.5 RPS MWD030 OHMM 3.22 2000 15.0311 12091 5304.5 11349.5 RPX MWD030 OHMM 0.11 1611.15 14.8514 12091 5304.5 11349.5 FET MWD030 HOUR 0.2 59.59 0.971251 12091 5304.5 11349.5 GR MWD030 API 32.77 123.35 81.4979 12062 5312 11342.5 ROP MWD030 FT/H 11.14 582.18 196.883 12084 5358.5 11400 First Reading For Entire File.......... 5304.5 Last Reading For Entire File ........... 11400 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 06/03/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name.............LISTPE Date.....................06/03/23 origin...................STS r Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Reel Trailer Service name.............LISTPE Date .....................06/03/23 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library Scientific Technical Services Scientific Technical Services
