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HomeMy WebLinkAbout206-154CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on CPAI Well 1J-136 on 01.30.23 Date:Monday, January 30, 2023 3:05:53 PM Attachments:image001.png KRU 1J-136 (PTD 2061540) 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: Monday, January 30, 2023 11:14 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: LPP/SSV Returned to Service on CPAI Well 1J-136 on 01.30.23 Good Morning Jim, The low-pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was returned to service and removed from the “Facility Defeated Safety Device Log” on 01/30/2023 at ~10am, as the well has been maintaining > 150psi on the injection tubing pressure since the offset producer was shut in. The LPP had been defeated on 11/18/2022 after a significant injection pressure reduction (due to well communication with an offset producer) could not satisfy the LPP. This notification is in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, November 18, 2022 8:49 AM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-136 on 11.18.22 The low-pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was defeated today 11/18/2022 at ~1:45 AKST, when the wellhead injection pressure dropped below LPP setpoint (150psi) as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct interference diagnostics on the nearby producer (1J-135) that we assume is in communication with this injector. The well is currently injecting at recommended rate of 600BWPD and wellhead pressure is at 115psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI Well 1J-136 on 11.18.22 Date:Friday, November 18, 2022 9:49:50 AM Attachments:image002.png Kuparuk River Unit 1J-136 (PTD 2061540) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, November 18, 2022 8:49 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/SSV on CPAI Well 1J-136 on 11.18.22 The low-pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was defeated today 11/18/2022 at ~1:45 AKST, when the wellhead injection pressure dropped below LPP setpoint (150psi) as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct interference diagnostics on the nearby producer (1J-135) that we assume is in communication with this injector. The well is currently injecting at recommended rate of 600BWPD and wellhead pressure is at 115psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com By Anne Prysunka at 3:11 pm, Oct 06, 2022 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-136 KUPARUK RIV U WSAK 1J-136 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-136 50-029-23331-00-00 206-154-0 W SPT 3503 2061540 1500 537 536 536 537 176 182 180 182 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-136 Inspection Date: Tubing OA Packer Depth 1180 1990 1940 1935IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509111046 BBL Pumped:2.5 BBL Returned:2.2 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:09:07 -08'00' Kray- (J -i5 Regg, James B (CED) Prh Z��I59D From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, October 31, 2020 4:16 PM To: Regg, James B (CED) Cc: CPF1 Ops Supv; CPF1 DS Lead Techs; Autry, Sydney; Thomson, Stephanie; Braun, Michael (Alaska); Mowrey, Andrew F Subject: LPP/SSV Returned to Service on Well 1J-136 on 10/31/2020 Jim, The low pressure pilot (LPP) on well U-136 (PTD #206-154, #206-155) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 10/31/2020, as the injection pressure increased above the LPP setpoint due to sustained injection in the pattern. The well is currently injecting 579 BWPD at 174 psi wellhead pressure. The LPP had been defeated on 10/12/2020 when the wellhead pressure had fallen below the LPP setpoint 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 / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Marina's Cell: (907) 399-7791 Pager: (907) 659-7000 4497 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, October 13, 2020 5:38 AM Ze�l 101i5keLv To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI Well 1J-136 on 10/12/2020 Jim, The low pressure pilot (LPP) on well well 1J-136 (PTD #206-154, #206-155) was defeated yesterday, 10/12/2020, after the wellhead pressure again fell below the LPP setpoint. The well is currently injecting 556 BWPD at 147 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." Thanks, Alex Trower on behalf of Toon Changklungdee / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska (785) 691-6746 (� 2061540 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophilIips.com> Sent: Friday, October 9, 2020 2:08 PM To: Regg, James B (CED) ` Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI Well 1J-136 on 10/9/2020 Hello Jim, In reference to the email below, the low pressure pilot on well 1J-136 (PTD #206-154, #206-155) has now been returned to normal service. Currently the well is injecting 613 BWPD at 380 psi wellhead pressure. Please let us know if you have any questions. Thanks, Alex Trower on behalf of Toon Changklungdee / Marina Krysinski West Sak Production Engineers Conoco Phillips Alaska (785) 691-6746 From: NSK West Sak Prod Engr Sent: Tuesday, September 8, 2020 4:42 PM To: Jim Regg <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophi Ilips.com>; Braun, Mic (Alaska) <Michael.Bra un@conocophillips.com>; Mowrey, Andrew F <Andrew.F.Mowrey@conoco ips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-136 on 9/8/2020 Jim, The low pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206- 5) was defeated today, 9/8/2020, when the wellhead pressure fell below the LPP setpoint. The well is currently ting 556 BWPD at 5 psi wellhead pressure. The LPP and surface safety valves (SSV) have been tagged and their �aius is recorded in the "Facility Defeated Safety Device Log." IZ 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, Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 1.5-13w Regg, James B (CED) F-Ii� From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, September 8, 2020 4:42 PMc'r'! L(6 12", Zz To: Regg, James B (CED) /I Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI Well 1J-136 on 9/8/2020 Jim, The low pressure pilot (LPP) on well U-136 (PTD #206-154, #206-155) was defeated today, 9/8/2020, when the wellhead pressure fell below the LPP setpoint. The well is currently injecting 556 BWPD at 5 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. Thank you, 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 lC2t,+, l�'-r3zP ni` ZD& 1740 Regg, James B (GED) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Tuesday, July 28, 2020 5;15 AM �� -7 x/2232 p A To: Regg, James B (CED) �� Cc: Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt Subject: LPP/SSV Returned to Service on Well 1J-136 on 7/26/2020 Jim, The low pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was returned to service and removed from the "Facility Defeated Safety Device Log" Sunday, 7/26/2020, as the injection pressure increased above the LPP setpoint. The well is currently injecting 613 BWPD at 197 psi wellhead pressure. The LPP had been defeated earlier in the day on 7/26/2020 when the well was returned to service after the completion of the planned CPF1 shutdown. This notification is 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 Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Sunday, July 26, 2020 10:28 AM r_7 j17(�c%Zt3 To: Regg, James B (CED) l� 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-136 on 7/26/2020 Jim, t/ The low pressure pilot (LPP) on well 11-136 (PTD #206-154, #206-155) was defeated today, 7/26/2020, when the well was returned to service after a three day shut-in period. The well is currently injecting 613 BWPD at 154 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. Thank you, 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 K2c. ICT- V 3 w zc/� 1540 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �J Sent: Sunday, July 12, 2020 12:43 PM I���l? Z/ l�ll'Zi1ZU To: Regg, James B (CED) C Cc: Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on Well 11-136 on 7/12/2020 Jim, The low pressure pilot (I -PP) on well 1J-136 (PTD #206-154, #206-155) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 7/12/2020 as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 480 BWPD at 160 psi wellhead pressure. The LPP had been defeated on 7/10/2020 when the well was returned to service after the completion of 1.1 water injection header replacement project. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thanks, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 44,2�A t T- ( 3w Pn�, zl�,I5-10 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophiIIips.com>�� 7/14 J?� Sent: Friday, July 10, 2020 4:32 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: Defeated LPP/SSV on CPAI Well 1J-136 on 7/10/2020 Jim, The low pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was defeated today, 7/10/2020, when the well was returned to service after the completion of 1J water injection header replacement project. The well is currently injecting 600 BWPD at 110 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." i The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval i No. CO 4068.001." Please let me know if you have any questions. Thank you, Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 1 1310 P� 20(x, /5+0 Reqq, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, June 8, 2020 2:38 PM To: Regg, James B (CED) Cc: Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F; CPH DS Lead Techs; CPF1 Ops Supv, CPF1&2 Ops Supt; NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on Well 1J-136 on 6/7/2020 Subject Correction From: NSK West Sak Prod Engr Sent: Monday, June 8, 2020 2:34 PM To: 'Regg, lames B (DOA)' <jim.regg@alaska.gov> Cc: Braun, Michael (Alaska) <Michael.Braun@conocophillips.com>; Autry, Sydney <Sydney.Autry@conocophillips.com>; Mowrey, Andrew F <Andrew.F.Mowrey@conocophillips.com>; CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com> Subject: Defeated LPP/SSV eR CP We'! 1 136 an 6 77 2020 LPP/SSV Returned to Service on Well 1J-136 on 6/7/2020 Jim, The low pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was returned to service and removed from the "Facility Defeated Safety Device Log" last night, 6/7/2020 as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 620 BWPD at 179 psi wellhead pressure. The LPP had been defeated on 5/28/2020 when the well was returned to service after well work was completed to open a second lateral for injection. 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) 6S9-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 KZ1 1,3z, PM 40b 1 S4c Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Thursday, May 28, 2020 12:11 PM ,4 51Z -61A) -Z-0 To: Regg, James B (CED) 1317 Cc: Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt Subject: Defeated LPP/SSV on CPAI Well 1J-136 on 5/28/2020 Jim, The low pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was defeated today, 5/28/2020, when the well was returned to service after well work was completed to open a second lateral for injection. The well is currently injecting 615 BWPD at 105 psi wellhead pressure. The LPP and surface safety valves (SSV) have been tagged and their_ status is recorded in t e Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Marina's Cell: (907) 399-7791 Pager: (907) 659-7000 #497 Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC -. ATTN: Natural Resources Technician 11 --� Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 >•& Anchorage, AK 99501 206154 30457 + • 14 -Mar -19 14Ma r19 -JW 01 WELL NAME 1R-17 1E-1681-1 1C-190 1J-164 ,. # 50-029-22212-00 50.029-23230.60 50.029-23136-00 50-029.23278-00 SERVICE ORDER EA77-00002 E90U-00005 E90U-00006 E90U-00007 FIELD NAME KUPARUK RIVER KUPARUKRIVER KUPARUK RIVER KUPARUK RIVER DESCRIPTION DELIVERABLE WL WL WL Memory DESCRIPTION IPROF Vert (PROF [PROF IPROF--j5-FINAL DATA FINAL FIELD FINAL FIELD FINAL FIELD FIELD Color D. r 13 -Feb -19 23 -Feb -19 23 -Feb -19 -Feb-19 r 1 1 1 1 1J-136 50-029-23331-00 E901.1-00009 KUPARUK RIVER Memory IPROF FINAL FIELD 26 -Feb -19 1 21111-21 50-103-20156-00 E540-00062 KUPARUK RIVER WL Caliper FINAL FIELD 7 -Mar -19 1 t 6 Signature return via courier or sign/scan and email a copy Date and CPAI. Schlumberger-PrNate ATransmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. IC2l( iT-U3, Prf� Z�* t54n Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Wednesday, February 27, 2019 7:01 AM V, 2/0-7/,, To: Regg, James B (DOA) fl Cc: NSK Optimization Engr; CPF1 DS Lead Techs; CPF1&2 Ops Supt; CPF1 Ops Supv; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara; CPF1 Prod Engr Subject: LPP/SSV Returned to Service on Well 1J-136 Jim, The low pressure pilot (LPP) on well 1J-136 (PTD #206-154, #206-155) was returned to service and removed from the "Facility Defeated Safety Device Log" last night, 2/26/2019, after diagnostic wellwork was completed and the well was shut-in. The LPP had been defeated on 12/28/2018 after the wellhead pressure fell below the LPP setpoint. This notification is 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 0 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 6lz- 1 DATE: Monday,May 14,2018 P.I.Supervisor I l� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1J-136 FROM: Lou Laubenstein KUPARUK RIV U WSAK 1J-136 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry��12-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-136 API Well Number 50-029-23331-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-154-0 Inspection Date: 5/9/2018 Insp Num: mitLOL180510144728 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IJ 136 Type Inj W JTVD i 3543 Tubing 383 383 ' 383 - 383 - I PTD_I 2061540 Type Test SPT Test psi j 1500 '1 IA 1220 2000 1955 - 1950 • BBL Pumped: 2.2 ' BBL Returned: 1.9 OA 180 I 183 - 184 - 186 -� Interval [ 4YRTST P/F I P Notes: SCANNED JUN 0 4 2018 Monday,May 14,2018 Page 1 of 1 rg, /1,5, • • Prb Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> //". Sent: Thursday, September 21, 2017 7:50 PM vl I ZZf 7 To: Regg, James B (DOA) (I l Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt; Effiong, Michael;Autry, Sydney Subject: LPP/SSV Returned to Service on CPAI well 1J-136 - 09/21/2017 Jim, The low pressure pilot(LPP) on well 1J-136 (PTD#206=154, 206-155)was returned to service and removed from the "Facility Defeated Safety Device Log" on 09/21/2017. The well is currently injecting at approximately 340 BWPD with a wellhead injection pressure of215 psi. The LPP had been defeated on 09/18/2017, after the wellhead injection pressure declined to nearly the LPP setpoint of 150 psi. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Scott Stanley / Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.comCANNE '" 3a 't':"rf 1 • • lIx ezi6/5-4-0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, September 15, 2017 8:27 PM G( 9 j le(17 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt; Effiong, Michael; Stanley, Scott M; Autry, Sydney Subject: LPP/SSV Returned to Service on CPAI well 1J-136 - 09/15/2017 Jim, The low pressure pilot(LPP) on we11,1J-136 206-154 206-155)was returned to service and removed from the "Facility Defeated Safety Device Log" on 09/15T2017. The well is currently injecting at approximately 300 BWPD with a wellhead injection pressure of 185 psi. The LPP had been defeated on 09/05/2017, after the well was restarted. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Pager: 1 907 659-7000 pg. #497 Email: n1638(a�conocophillips.com 1 I STATE OF ALASKA AL OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MARCIT GEL MBE CI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Name: p Development❑ Exploratory❑ 206-154 3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-23331-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1.1-136 ADL 25662,ADL 380058,ADL 25661 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 17,507 feet Plugs measured None a.ECEIVED true vertical 3,489 feet Junk measured None feet SEP 1 1 2017 Effective Depth measured 17,495 feet Packer measured 9023, 9197 feet AOGC ► true vertical 3,488 feet true vertical 3543, 3568 feet L�JJ Casing Length Size MD TVD Burst Collapse 34"INSULATED 78 feet 20 " 121' MD 121 TVD SURFACE 3,458 feet 13 3/8" 3,501' MD 2236 TVD INTERMEDIATE 9,688 feet 9 5/8" 9,730' MD 3631 TVD LINER B-SAND 8,298 feet 5 1/2" 17,495' MD 3528 TVD Tubing(size,grade,measured and true vertical depth) 4.5 " L-80 9,058' MD 3,547'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=SL ZXP Liner Top Packer 9,023' MD 3,543'TVD PACKER= HRD ZXP Liner Top Packer 9,197' MD 3,568'TVD SSSV = NONE N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 2U1� SCANNED DEC 1 4 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: SHUT-IN — — — — Subsequent to operation: SHUT-IN — — — — 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service I] Stratigraphic El Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR El WINJ I] WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 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: 317-222 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr.Wells Engineer A/ / / y Contact Phone: (907)265-6471 Authorized Signature: et �✓ Date: 9/ / '/ 7 f Form 10-404 Revised 4/2017 VTL 100?-1/ RBDMS � � ; 201/ Submit Original Only 7.941, 7 MS f • • 1J-136 DTTMST)JOBTYP SUMMARYOPS 8/15/17 MISC. MARCIT GEL TREATMENT: PUMPED 50 BBLS OF 80*2% KCL, 20 BBLS CAPACITY OF 78* LINEAR MARCIT GEL, 45 BBLS OF 75*CROSSLINKED MARCIT SUSTAINMENT GEL, FOLLOWED BY 30 BBLS OF 75* LINEAR MARCIT GEL DOWN THE TUBING. DISPLACED TUBING W/ 144 BBLS OF 60* DIESEL. 8/25/17 PUMPING PUMP 45 BBLS DIESEL DOWN TUBING FROM CHRISTENSEN TRACKING ONLY VALVES FOR FREEZE PROTECT JOB COMPLETE KUP a 1J-136 ConocoPhillips Well AttributIIII Max Angle. . TD Alaska,inc.. Wellbore APUUWI Field Name Wellbore Status ncl 01 MD(ftKB) Act Btm(ftKB) g(trl 500292333100 WEST SAK INJ 17,507.0 L ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Mwople Laterals-1J-13s,9nr2017 1090-61 AM SSSV:•NIPPLE Last WO: 44.00 1/3/2007 - • Vertical schematic(acwer). Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - - - - Last Tag: Rev Reason:MARCIT JOB see NOTES pproven 9/6/2017 HANGER;37.8 ,fjt,. - Lasing Strings Casing Description OD(Ln) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 34"Insulated; al_"••-. PCONDUCTOR 34" 20 19.250 42.9 121.0 121.0 94.00 K-55 WELDED LE. 01.0 - 505.5 Insulated NIPPLE; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 13 3/8 12.415 42.9 3,501.0 2,236.2 68.00 L-80 Buttress INJECTION;2,211.4 Thread Casing Description OD(Ln) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)...'WULen a...Grade Top Thread nimo Window D-Sand 12 10._0.00 9,090.0 9,100.0 3,552.9 40.00 L-80 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'WULen(L..Grade Top Thread INTERMEDIATE 9 5/8 8.835 41.4 9,729.7 3,631.0 40.00 L-80 BTC-M SURFACE;429-3,501 0--. Casing Description OD(IM ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD...WULen(L..Grade Top Thread SLEEVE-C;8,989.7 D-Sand Liner HH 5 1/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L-80 BTC-M _Alg_ Liner Details l• a Nominal ID LOCATOR;9,039.4 i Top(ftKB) Top(TVD)(ftKB) Top Incl y) Item Des Conn (in) SEAL ASSY;9,040.5 9,082.9 3,550.6 82.48 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 7.660 BTC 9,104.3 3,553.5 82.05 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 5.020 ISO SLEEVE;9,070.0 '1I I's BTC Window D-Sand;9,090.0- 9,100.0I i 9,236A 3,574.2 80.34 ECP Baker Payzone Packer 4.930 9,261.5 3,578.4 80.17'XO-reducing 5.5"x4.5" 1930 1i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread Liner B-Sand 51/2 4.750 9,196.8 17,495.0 3,528.4 15.50 L80 BTCM r MI Liner Details Alt Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl0) Item Des Corn (in) D.Sand Liner LEM;9,023.1- 8,z4o.o - 9,196.8 3,567.6 80.61 PACKER "HRD"ZXP Liner Top Packer 9-5/8"(7.50"X 8.43") 7.650 9,215.4 3,570.7 80.48 NIPPLE "RS"Packoff Seal Nipple 7.00"(6.19"ID x 7.65"0 7.650 D-Sand Liner HH;9,082.9- 9,219.4 3,571.3. 80.46 HANGER FlexLock Liner Hanger 7"x 9-5/8"(6.23"X 8.34") 6.230 9,348.8 9,227.2 3,572.6' 80.40 XO BUSHING XO Bushing 4.90"ID,7.67"OD 4.900 9,228.9 3,572.9' 80.39 SBE 190-47 Casing Seal Bore Ext.4.75"10 x 6.31"OD 4.750 INTERMEDIATE;41.4-9,729.7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-Sand Liner LEM 4 1/2 3.958 9,023.1 9,240.0 3,574.8 12.60 L-80 IBTM Liner Details SLOTS;9,750.0-10,240.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top!noir) Item Des Com (in) 9,023.1 3,542.7' 82.20 PACKER ZXP 7"x 9-5/8"Liner Top Packer,8.43"OD x 7.5"ID. 7.500 IPERF;10,173.0-10,178.0 "s- SL ZXP liner top packer w/Bi-directional slips.Size 7"x 9-5/8". _ 9,044.3 3,545.6 82.41 XO-reducing X-Over,7"x 5-1/2"Hydril 563 7.67 OD x 4.92"ID 4.920 9,045.7 3,545.8 82.43 SBR 190-47 Casing Seal Bore Receptacle 6.31"OD x 4.750 SLOTS;10.558.0-11,058.0 4.75"ID 9,065.4 3,5483 82.62 XO Bushing X0 Bushing 5-1/2"Hydril 563 x 4-1/2"IBT 6.00"OD 3.940 x 3.94" 9,070.6 3,549.0 82.67 HANGER PZ LEM above Hook Hanger 7.65"x 3.68"ID.Size: 2.500 4-1/2"x 9-5/8"(ISO SLEEVE 11 26 15;3.68"X 18' - - 2.501D-RECOVERED 7/30-2016) SLOTS;11.371.0-11,821.0 - 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65"x 3.68"ID.Size:4 3.688 _ -1/2"x 9-5/8" • 9,133.7 3,557.7 81.47 NIPPLE Camco"DB-6"Nipple,I.D.3.562",IBT.4-1/2"DB 6 3.562 Landing nipple(DB PLUG IN NIPPLE&PRONG IN PLUG-3.562"x11'OAL-7/30/2016) 9,236.7 3,574.2' 80.34 SEAL Baker Seal Assembly 4-1/2"STL Box up 4.74"seals 3.880 SLOTS:12,136.0-12,635.0-,. ._ x 3.88"ID.Non-locating seal assembly w/full mule shoe. _ _ Tubing Strings --- _ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Iblft) Grade Top Connection TUBING 41/2 3.958 37.8 9,057.5 3,547.3 12.60 L-80 IBT-mod Completion Details SLOTS;12,989.0-13,439.0 - Nominal ID Top(ftKB) Top(ND)(ftKB) Top Mel(") Item Des Corn (Ln) 37.8 HANGER Vetco Gray 11"x 4-1/2"wl 4.909"MCA Top Connection 3.958 _ _ (Pup 4.36') 505.5 505.5 7.06 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 8,989.7 3,538.1 81.87 SLEEVE-C Baker CMD Sliding Sleeve w/Camco 3.812"'DB'Profile 3.812 SLOTS;13,752.0-14,246.0 _ (CLOSED 12/13/11) 9,039.4 3,544.9 82.37 LOCATOR Baker Locator 5.16"0.0. I.D.3.95".GBH-22 Locating 3.958 seal assembly 9,040.5 3,545.1 82.38 SEAL ASSY Baker 4.74"SBE Seal Assy. 3.880 - _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SLOTS;14,561.0-15,020.0 .- Top(TVD) Top Incl Top(ftKB) (ftKB (1 Des Com Run Date ID(in) 9,070.0 3,548.9 82.67 ISO SLEEVE TYPE 1 ISO SLEEVE 8/11/2017 2.500 Perforations&Slots Shot Den SLOTS;15,347.0-15.848.0 _ .-- Top(ftKB) Bim(ftKB T pu(B)op ) B(ftKB)D) Zone Date 1s ft) Type Corn 9,750.0 10,240.0 3,632.2 3,634.8 WS B,1J-136 12/10/2006 32.0 SLOTS ALL PERFS IN WELLBORE:Alternating - _ solid/slotted pipe- - 0.125"x2.5"@ 4 sCors.16,165.0-16,415.0 _ circumferential adjacent rows,3"centers staggered 18 deg,3'non -- = -slotted ends -- - 10,173.0 10,178.0 3,637.9 3,637.7 WS B,1J-136 12/14/2011 6.0 IPERF 31 BIG HOLE SLOTS;17.003.0-17,455.0 _ _1 Liner BSand;9.198.8-17.495.0 1 Li KUP I • 1J-136 ConocoPhillips Z Aask:-3.int:. Conde Phillips •-- Multiple Laterals-1J-136,917/2017 10:20-.51 AM. Vertical schematic(actual) HANGER 37.8 'r1)e ,,•"°r"r""r""""""""";."'"""' lilt Perforations&Slots a Shot CONDUCTOR 34"Insulated; . Dens ../.... 42.9-121.0 Top(TVD) Btm(TVD) (shots/ NIPPLE;505.5 . Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date ft) Type Com 10,558.0 11,056.0 3,608.4 3,609.8 WS B,1J-136 12/10/2006 32.0 SLOTS INJECTION;2,211.4 11,371.0 11,821.0 3,606.4 3,594.8 WS B,1J-136 12/10/2006 32.0 SLOTS 12,136.0 12,635.0 3,584.5 3,578.5 WS B,1J-136 12/10/2006 32.0 SLOTS • SURFACE;42.9-3,501.0 SLEEVE-C,111.906.7 12,989.0 13,439.0 3,573.0 3,564.1 WS B,1J-136 12/10/2006 32.0 SLOTS illi 13,752.0 14,246.0 3,557.7 3,552.5 WS B,1J-136 12/10/2006 32.0 SLOTS LOCATOR;9,039.4 ,. .L SEAL ASSY;9,040.5 14,561.0 15,020.0 3,549.0 3,541.9 WS B,1J-136 12/10/2006 32.0 SLOTS ISO SLEEVE;9,070.0 -,l Ij, 15,347.0 15,848.0 3,541.4 3,539.1 WS B,1J-136 12/10/2006 32.0 SLOTS W,ndow Dsand;9,090.0- 4I; k.f 9.100° ill 16,165.0 16,415.0 3,543.1 3,554.6 WS B,17-136 12/10/2006 32.0 SLOTS 17,003.0 17,455.0 3,536.5 3,526.7 WS B,1J-136 12/10/2006 32.0 SLOTS *kWh Mandrel Inserts St D-Sand Liner LEM;9,023.1- ati 9.240.0 on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn o-sandLiner NH;e,aers 1 2,211.4 1,907.9 CAMCO KBMG 1'INJ DMY 'BK-5 0.000 0.0 4/2/2007 9,346.0- Notes:General&Safety End Date Annotation 1/1/2007 NOTE: MULT-LATERAL WELL,17-136(B/C-SANDS),1J-136L1(D-SANDS) INTERMEDIATE;41 4-9,728.7 4/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 _ _ 12/15/2011 NOTE:PROFILE MODIFICATION-PUMPED 1776 LBS(4MM)CRYSTAL SEAL"B"MBE@10175 SLOTS;9,750.0-10,240.0 4/28/2016 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 420 BBLS OF SEA WATER WITH 45108 OF 4 MM — — CRYSTAL SEAL (PERF;10,173.010,178.0 _ 4/28/2016 NOTE:NET PRESSURE INCREASE OF-1000 PSI. 8/15/2017 NOTE:MARCIT Treatment was pumped to B MBE. — SLOTS;10.558.0-11,056.0—..-. SLOTS,11,371.0-11,821.0 - — SLOTS 12,136.0-12,835.0 SLOTS,12,989.0-13,4390 =' = SLOTS;13,752.0-14,248.0 SLOTS;14,561.0-15,020.0 SLATS;15,347.0-15,848.0 — SLOTS;16,165.0-16,415.0 SLOTS;17,003.017,455.0 4.- LIMN' Liner 6-Sand;9,198.8-17,495.0 i • 4 IJ l3& Pro 2 ,is-40 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> q161,Sent: Tuesday, September 5, 2017 9:35 PM I�L'�, 7 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;Jensen, Marc D;Autry, Sydney; Krysinski, Marina L; Sullivan, Michael;Targac, Gary; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1J-136 on 9/05/2017 Jim, The low pressure pilot (LPP) on well 1J-136 (PTD# 2061540, 2061550)was defeated today, 9/05/2017, after the well was put on water injection service following a shut-in period. The well is currently injecting at a wellhead infection pressure of 7 psi and rate of 247 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety D_ evice Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best Regards, Scott Stanley /Michael Effiong West Sak Production Engineers ConocoPhillips Alaska,Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCANNED r E,B • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,August 6, 2017 9:15 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1J-136 (PTD 206-154) update 8-6-17 Attachments: 1J-136 90 day TIO 8-6-17.JPG Chris, The 30 day monitor period for 1J-136 is coming to an end and integrity of the tubing has been confirmed based on review of the trend plot. The cycling of the sliding sleeve does look like it repaired the previously identified TxIA communication. The well is now being returned to its'normal' status. Attached is the updated 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. ,, �(� ' Desk Phone(907) 659-7224 scoo.® r Mobile Phone (907)943-0170 From: NSK Well Integrity Supv CPF1 and 2 Sent:Thursday,July 06,2017 7:49 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: Report of IA pressure anomaly 1J-136(PTD 206-154) update 7-6-17 Hi Chris, Today,the coiled tubing unit was deployed to 11-136 to investigate the failed MITIA. The sliding sleeve at 8990'was cycled and we were able to get a follow-up passing MITIA. CPAI intends to return the well to water injection and monitor for 30 days to confirm the communication no longer exists. A followup email will be provided at the conclusion of the monitor. Please let us know if you disagree with the plan forward. Attached is the MIT data. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone(907)943-0170 From. , - Integrity Supv CPF1 and 2 Sent:Wednesday,June , ! 12:39 PM To:Wallace,Chris D (DOA)<chris.wa . a. .ska.:ov> Cc:Senden, R.Tyler<R.TvIer.Senden@conocophillip . Subject: RE: Report of IA pressure anomaly 11-136(PTD 206-15A s .: - e 6-21-17 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday,July 6, 2017 7:49 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1J-136 (PTD 206-154) update 7-6-17 Attachments: MIT KRU 1J-136 Diagnostic 7-6-17.xlsx Hi Chris, Today,the coiled tubing unit was deployed to 1J-136 to investigate the failed MITIA. The sliding sleeve at 8990'was cycled and we were able to get a follow-up passing MITIA. CPAI intends to return the well to water injection and monitor for 30 days to confirm the communication no longer exists. A followup email will be provided at the conclusion of the monitor. Please let us know if you disagree with the plan forward. Attached is the MIT data. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. 20 Desk Phone(907) 659-7224 SCANNED AUG 0 Mobile Phone(907)943-0170 From: NSK Well Integrity Supv CPF1 and 2 Sent:Wednesday,June 21, 2017 12:39 PM To. allace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Se .en, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: R 'eport of IA pressure anomaly 1J-136(PTD 206-154) update 6-21-17 Chris, 1J-136 failed its diagnost . MITIA last night when we could not achieve test pressure. The well was shut in this morning. Well intervention = k will be pursued to identify the leak location. Once a path forward is established and prior to returning the well to injec '•n,appropriate paperwork will be submitted. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907)943-0170 From: NSK Well Integrity Supv CPF1 and 2 Sent:Saturday,June 17, 2017 8:45 AM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tvler.Senden@conocophillips.com> Subject: Report of IA pressure anomaly 1J-136(PTD 206-154) 6-17-17 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday,June 21, 2017 12:39 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1J-136 (PTD 206-154) update 6-21-17 Chris, 1J-136 failed its diagnostic MITIA last night when we could not achieve test pressure. The well was shut in this morning. Well intervention work will be pursued to identify the leak location. Once a path forward is established and prior to returning the well to injection,appropriate paperwork will be submitted. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. SCANNED jUN 2 3201./ Desk Phone(907)659-7224 Mobile Phone(907)943-0170 From: NSK Well Integrity Supv CPF1 and 2 Sent:Saturday,June 17,2017 8:45 AM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: Report of IA pressure anomaly 1J-136(PTD 206-154)6-17-17 Chris, West Sak water injector 1J-136 (PTD 206-154) is experiencing an IA pressure anomaly. Two days ago,the IA unexpectedly lost pressure. The IA pressure is now fluctuating near the injection pressure of"650psi. Last night the drillsite operator attempted to pressurize the IA using gas with no success. DHD will begin the initial suite of diagnostics to include packoff testing and MITIA/LLR as needed. If the MIT fails,the well will be shut in and freeze protected as soon as possible with followup well intervention work as needed. But if the MIT passes,a differential between the tubing and IA will be established and the well will be monitored for 30 days. A followup email will be provided at the conclusion of the diagnostics. Please let us know if you disagree with the path forward. Attached are the schematic,90 day TIO plot and 3 day SCADA snapshot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 Mobile Phone (907)943-0170 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday,June 17, 2017 8:45 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly 1J-136 (PTD 206-154) 6-17-17 Attachments: 1J-136 90 day TIO 6-17-17 jpg; 1J-136 schematic.pdf; 1J-136 3 day TIO plot 6-17-17.JPG Chris, West Sak water injector 1J-136 (PTD 206-1541 is experiencing an IA pressure anomaly. Two days ago,the IA unexpectedly lost pressure. The IA pressure is now fluctuating near the injection pressure of^'650psi. Last night the drillsite operator attempted to pressurize the IA using gas with no success. DHD will begin the initial suite of diagnostics to include packoff testing and MITIA/LLR as needed. If the MIT fails,the well will be shut in and freeze protected as soon as possible with followup well intervention work as needed. But if the MIT passes, a differential between the tubing and IA will be established and the well will be monitored for 30 days. A followup email will be provided at the conclusion of the diagnostics. Please let us know if you disagree with the path forward. Attached are the schematic, 90 day TIO plot and 3 day SCADA snapshot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 Mobile Phone (907)943-0170 ED ,j1Jil 2 3 20 i,!, 1 ti OF ? • • �\�yy,'• THE STATE Alaska Oil and Gas A /� LAConservation Commission KA 333 West Seventh Avenue 1. GOVERNOR BILL WALKER1011 Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce StANNED j 1.j N 0 9 2 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-136 Permit to Drill Number: 206-154 Sundry Number: 317-222 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster / Chair � DATED this 1� y of June,2017. RBDMS LAW - 7 2017 • • RECEIVED STATE OF ALASKA JUN 01 207 ALASKA OIL AND GAS CONSERVATION COMMISSION /YTS 6 /L.J it-7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well 0 Operations shutdown12 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: MARCIT GEL MBE 0, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development D 206-154 ' 3.Address: 6.API Number: Stratigraphic ❑ Service ❑ P. O. Box 100360,Anchorage,Alaska 99510 50-029-23331-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 J-136 • Will planned perforations require a spacing exception? Yes 0 No El / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25662,ADL 380058,AL 25661 ' Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 17,507' , 3,489' , 17495 , 3488 , 1475 psi 9133 NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 121' 121' Surface 3,458' 13 5/8 3,501' 2,236' Intermediate 9,688' 9 5/8 9,730' 3,631' Liner B Sand 8,298' 5 1/2 17,495' 3,528' Perforation Depth MD(fti: Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9750-1.3439" j os 3632-3564 4.500" L-80 9,057' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=SL ZXP Liner Top Packer ' 9023 MD,3543 TVD PACKER=HRD ZXP Liner Top Packer - 9197 MD,3568 ND SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic❑ Development 0 Service 0 ' 14.Estimated Date for (bi/itb frf 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ [ . WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@conocophillips.com � (� Contact Phone: (907)265-6471 Authorized Signature: -' A.11,,,,14...1– w ' „c Date: 512_6/17 �� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' — 2 22 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 (.I4)'14 Other: Post Initial Injection MIT Req'd? Yes 0 No V Spacing Exception Required? Yes ❑ No IF( Subsequent Form Required: J0 - .40 4" RBDMS C,,--"'" - 7 7fl17 APPROVED BY C y / 7 Approved by: /,/J ; COMMISSIONER THE COMMISSION Date: ?i /,/, , 6I' r VTC (,1 j7 G Np pp Submit Form and Form 10-403 Revised 4/2017 ' I a on is valid for 12 months from the date of a rOV81. Attachments in Duplicate • • Proposal 1J-136 to 1J-135 B MBE Retreatment with MARCIT Gel 1J-136 dual-lateral injector was completed December 2006 in West Sak B and D sands. The well has 4-1/2" L-80 tubing and both laterals have 5-1/2" slotted liners with Constrictors (Swell Packers). A Matrix Bypass Event (MBE) occurred 2/23/10 in 1 J-136 B lat to 1 J-135 B lat producer. A 3/15/11 IPROF in 1J-136 showed a B MBE between 10150 - 10680' MD. This interval is partly covered by 358' of blank liner. Most PWI was exiting the liner above the blank. On 12/14/11, 'big hole' perfs were shot at 10173 - 10178' RKB. On 12/15/11, CT pumped 1776 lbs Crystal Seal (CS) to seal the B MBE, then excess Gel was cleaned out with CT to restore PWI to both D & B laterals. This MBE treatment lasted a few years. On 8/9/15, an IPROF detected 93% PWI split entering the B lateral. PWI continued until a B MBE occurred 9/19/15. An IPROF on 11/27/15 in the B Lat saw a temperature anomaly at —10650' RKB indicating the presence of a B MBE. On 2/2/16, large hole perfs were shot at 10625 - 10630' RKB. On 4/28/16, 4510 lbs Crystal Seal was pumped to the MBE down CT. This MBE treatment only lasted —3 months. A 7/29/16 IPROF showed the MBE at —10650' RKB was open again. On 10/12/16, a MARCIT Gel job was attempted on the MBE, but operational difficulties during the job resulted in only linear Gel pumped to size the MBE, but no crosslinked MARCIT was ever pumped. It is proposed that a fullbore MARCIT Gel placement be reattempted to seal the 1J-136 B MBE at 10650' RKB./A similar MARCIT MBE treatment of 10/13/16 on 1J-102 continues to be successful. 1J-136 Proposed Procedure: Coil Tubing: 1) RIH & pull the DB Plug set in the DB Nipple at 9133' RKB to open the B lateral for the B MBE treatment. 2) RIH & set an Iso-Sleeve in the D LEM at 9070' RKB to isolate the D lateral. Pumping: 3) MIRU Gel Pumping Unit equipment to perform fullbore MARCIT Gel job. Fullbore pump MARCIT Gel job down 4.5" Tubing to the B MBE as follows while monitoring treating pressure response in 1J-135 producer. Inject up to 500 bbls (max target) of accelerated viscosity MARCIT, followed by 12 hrs SI time to build Gel viscosity in the B MBE at —10650' RKB, then resume pumping up to 1000 bbls (max target) of regular MARCIT to complete the MBE treatment. Displace Gel to MBE with Seawater and Diesel FP. Leave well SI for at least 5 days, then return 1J-136 to PWI and monitor offset producer 1J-135 performance. Coil Tubing: 4) RIH with Jet Swirl Nozzle to jet through excess MARCIT Gel left in the B lateral liner to as deep as possible jetting Seawater. POOH & FP with Diesel. RD. 4) Run post-treatment memory IPROF log in B lateral to verify the B MBE is sealed. 5) RIH & pull D Iso-Sleeve to restore PWI to the D lateral. Return 1J-136 to PWI service to the West Sak B & D sands. JWP 5/31/2017 KUP 10 1J-136 ConoeoPh(I1ip5 Well Attributes Max Angle. TD Alas1k3.If1(; Wellbore APIIUWI Field Name Wellbore Status incl(°) MD(ftKB) Act Btm(ftKB) • co„.4p 101ipc 500292333100 WEST SAK INJ 17,507.0 --- « Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Maniple Laterals-1J-136,523/20171241 10 PM SSSV:NIPPLE Last WO: 44.00 1/3/2007 Vertralschemabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET DBPRONG, DB PLUG in DB pproven 11/20/2016 HANGER;37.8-. =1I.'..r. NIPPLE,PULL TYPE 1 ISO ,u.,„,,,,a„n,,,,,,nre,.e,.,r„,,.,,., f icon illi Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 34 InsulCONDUCTOR 34" 20 19.250 42.9 121.0 121.0 94.00 K-55 WELDED NIPPLE;;505 -4,...,-4,..., 42.9-121.0 55.5 Insulated Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread SURFACE 13 3/8 12.415 42.9 3,501.0 2,236.2 68.00 L-80 Buttress INJECTION;2,211.4 Thread Am Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread lams Atm Window D-Sand 12 10.000 9,090.0 9,100.0 3,552.9 40.00 L-80 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;429-3,501.0-i, INTERMEDIATE 95/8 8.835 41.4 9,729.7 3,631.0 40.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SLEEVE-c;8,989.7 D-Sand Liner HH 5 1/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L-80 BTC-M _ Liner Details ; � Nominal ID LOCATOR,9,039.4 _ L Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) SEAL ASSY;9,040.5 - 9,082.9 3,550.6 82.48-HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 7.660 _`.asr� BTC 9,104.3 3,553.5 82.05 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 5.020 WindowD-Sand;9,090.6_F11 I. BTC 9,100.0 9,236.4 3,574.2 80.34 ECP Baker Payzone Packer 4.930 �. 9,261.5 3,578.4 80.17 XO-reducing 5.5"x4.5" 3.930 PLUG;9,133.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade [Top Thread Liner B-Sand 51/2 4.750 9,196.8 17,495.0 3,528.4 15.50 L80 [Top IM Liner Details 0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) D-Sand Liner LEM;9,023.1- 9,240.0 ' a, 9,196.8 3,567.6 80.61 PACKER "HRD"ZXP Liner Top Packer 9-5/8"(7.50"X 8.43") 7.650 9,215.4 3,570.7 80.48 NIPPLE "RS"Packoff Seal Nipple 7.00"(6.19"ID x 7.65"0 7.650 D-Sand Liner HH;9,082.9- 9,219.4 3,571.3 80.46 HANGER FlexLock Liner Hanger 7"x 9-5/8"(6.23"X 8.34") 6.230 9,348.5 9,227.2 3,572.6 80.40 XO BUSHING XO Bushing 4.90"ID,7.67"OD 4.900 9,228.9 3,572.9 80.39 SBE 190-47 Casing Seal Bore Ext.4.7510 x 6.31"OD 4.750 INTERMEDIATE;41.4-9,728.7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(91(13) Set Depth(TVD)... Wt/Len(I...Grade Top Thread D-Sand Liner LEM 4 1/2 3.958 9,023.1 9,240.0 3,574.8 12.60 L-80 IBTM Liner Details SLOTS;9,750.610,240.0 Nominal ID - Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 9,023.1 3,542.7 82.20 PACKER ZXP 7"x 9-5/8"Liner Top Packer,8.43"OD x 7.5"ID. 7.500 IPERF;10,173.0-10,178.0 - , SL ZXP liner top packer w/Bi-directional slips.Size 7"x 9-5/8". 9,044.3 3,545.6 82.41 X0-reducing X-Over,7"x 5-1/2"Hydril 563 7.67 OD x 4.92"ID 4.920 9,045.7 3,545.8 82.43 SBR 190-47 Casing Seal Bore Receptacle 6.31"OD x 4.750 SLOTS;10,558.0-11,058.0 4.75"ID - 9,065.4 3,548.3 82.62 XO Bushing X0 Bushing 5-1/2"Hydril 563 x 4-1/2"IBT 6.00"OD 3.940 x 3.94" - 9,070.6 3,549.0 82.67 HANGER PZ LEM above Hook Hanger 7.65"x 3.68"ID.Size: 2.500 4-1/2"x 9-5/8"(ISO SLEEVE 11 26 15;3.68"X 18' - 2.5010-RECOVERED 7/30-2016) SLOTS;11,371.9-11,8210 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65"x 3.68"ID.Size:4 3.688 -1/2"x 9-5/8" 9,133.7 3,557.7 81.47 NIPPLE Camco"DB-6"Nipple,I.D.3.562",IBT.4-1/2"DB 6 3.562 _ Landing nipple(DB PLUG IN NIPPLE 8 PRONG IN PLUG-3.562"x11'OAL-7/30/2016) 9,236.7 3,574.2 80.34 SEAL Baker Seal Assembly 4-1/2"STL Box up 4.74"seals 3.880 SLOTS;12,136.0-12,635.0 ._ x 3.88"ID.Non-locating seal assembly w/full mule _ shoe. Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 37.8 9,057.5 3,547.3 12.60 L-80 IBT-mod - Completion Details SLOTS;12,989.613,439.0 _ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl ft) Item Des Com (in) ( 37.8 HANGER Vetco Gray 11"x 4-1/2"w/4.909"MCA Top Connection 3.958 (Pup 4.36') 505.5 505.5 7.06 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 8,989.7 3,538.1 81.87 SLEEVE-C Baker CMD Sliding Sleeve w/Camco 3.812"'DB'Profile 3.812 SLOTS;13752.614,248.0 (CLOSED 12/13/11) 9,039.4 3,544.9 82.37 LOCATOR Baker Locator 5.16"0. I .3.95".GBH-22 Locating 3.958 seal assembly 9,040.5 3,545.1 82.38 SEAL ASSY Baker 4.74"SBE Seal Assy. 3.880 - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SLOTS;14,561.615,020.0 j Top(ND) Top Incl Top(ftKB) (ftKB) 1'1 Des Corn Run Date ID(in) - 9,133.0 3.557.6 81.49 PLUG DB PLUG 8 PRONG IN IN NIPPLE 11/10/2016 0.000 Perforations&Slots shot Den D) SLOTS;15,347.0-15648.0-, Top(ftKB) Btm(ftKB) Top(ftKB) Bt(ft08)D) Zone Date (sho Type Com _ 9,750.0 10,240.0 3,632.2 3,634.8 WS B,1J-136 1200/2006 32.0 SLOTS ALL PERFS IN WELLBORE:Alternating - - solid/slotted pipe- - - 0.125"x2.5"@ 4 SLOTS,16,165.0-16,415 _ circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 10,173.0 10,178.0 3,637.9 3,637.7 WS B,1J-136 12/14/2011 6.0 (PERF 31 BIG HOLE SLOTS;17,003.617,455.0 =1 liner B-Sand;9,196.8-17,495.0,_.1 L S KUPI. . 1J-136 Con©c Phillips Al00kd,111C. 0.03;- philBps ,. ••' Multiple Laterals-1J-136,5/23/2017 12:41.11 PM Vertical schematic(actual). 111 HANGER,37 a- 111Perforations&Slots Shot CONDUCTOR 34"Insulated; Dens 42.9-121.0 Top(TVD) Btm(TVD) (shots/ NIPPLE;505.5 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 10,558.0 11,056.0 3,608.4 3,609.8 WS B,1J-136 12/10/2006 32.0 SLOTS INJECTION;2,211.4 11,371.0 11,821.0 3,606.4 3,594.8 WS B,1J-136 12/10/2006 32.0 SLOTS 12,136.0 12,635.0 3,584.5 3,578.5 WS B,1J-136 12/10/2006 32.0 SLOTS SURFACE,42.9-3,501.0--,— SLEEVE-C;8,988.7 12,989.0 13,439.0 3,573.0 3,5641 WS B,1J-136 12/10/2006 32.0 SLOTS .1, 13,752.0 14,246.0 3,557.7 3,552.5 WS B,13-136 12/10/2006 32.0 SLOTS LOCATOR;9,039.4 • J SEAL ASSY;9,040.5 14,561.0 15,020.0 3,549.0 3,541.9 WS B,1J-136 12/10/2006 32.0 SLOTS Window D-Send;9,080.0-�� .4b . . 15,347.0 15,848.0 3,541.4 3,539.1 WS B,1J-136 12/10/2006 32.0 SLOTS 9,100.0 16,165.0 16,415.0 3,543.1 3,554.6 WS B,13-136 12/10/2006 32.0 SLOTS PLUG;9,133.0 �/1 `{ 17,003.0 17,455.0 3,536.5 3,526.7 WS B,1J-136 12/10/2006 32.0 SLOTS Mandrel Inserts St D-Sand Liner LEM;9,023 ati 9,,2405 0 oft .0 onValve Latch Port Size TRO Run N Top(TVD) . _ Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 0-Sand Liner HH;9,082.9- 1 2,211.4 1,907.9 CAMCO KBMG 1 INJ GLV BK-5 0.188 1,450.0.1/28/2007 3.30 9,3465 Notes:General&Safety End Date Annotation 1/1/2007 NOTE: MULT-LATERAL WELL,1J-136(B/C-SANDS),1J-136L1(D-SANDS) INTERMEDIATE;41 4-9,729.7 4/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 12/15/2011 NOTE:PROFILE MODIFICATION-PUMPED 1776 LBS(4MM)CRYSTAL SEAL"B"MBE@10175 SLOTS;9,750.0-10,240.0 4/28/2016 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 420 BBLS OF SEA WATER WITH 4510#OF 4MM CRYSTAL SEAL (PERF;10,173.0-10,178.0 ww-+ z 4/28/2016 NOTE:NET PRESSURE INCREASE OF-1000 PSI. SLOTS,10,558.0-11056.0 SLOTS;11,371.0-11,821.0 = SLOTS;12,136.0-12,635.0 SLOTS;12,989.0-13,439.0 .- SLOTS;13,752.0-14,246.0 SLOTS;14,561.0-15,020.0 -. SLOTS;15,347.0-15,848.0 _ SLOTS,16165.0-16,415.0 _ SLOTS;17,003.0-17,455.0 _ Liner B-Sand;9,196.9-17,495.0+ • • ! Bettis, Patricia K (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Thursday,June 1, 2017 3:51 PM To: Bettis, Patricia K(DOA) Subject: RE: [EXTERNAL]KRU 11-136(PTD 206-154): Sundry Application Patricia, I went back to the original 1J-136 Liner Detail for the B Sand lateral and have verified that it shows bottom of the slots is at 17455'. The well schematic for 1J-136 also lists the bottom of deepest slots at 17455'. The perf depth listed on the 1J-136 10-403 Sundry should have been listed as 9750- 17455'. I apologize for the error. We try to verify all data is correct on the forms, but it looks like we missed this error. I'll gladly get the error corrected and resubmit the 10-403 if you wish. Please advise. Thanks, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,June 01, 2017 2:23 PM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]KRU 1J-136 (PTD 206-154): Sundry Application Good afternoon John, On Form 10-403, Section 11.Perforation Depth, past Reports of Sundry Well Operation show the perforation/slot depths from 9750-17455'. On the recent sundry application submitted, perforation depth are listed as 9750-13439'. Please verify which is currently correct for KRU 1J-136. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,June 1, 2017 2:23 PM To: Peirce,John W(John.W.Peirce@conocophillips.com) Subject: KRU 1J-136 (PTD 206-154): Sundry Application Good afternoon John, On Form 10-403, Section 11.Perforation Depth, past Reports of Sundry Well Operation show the perforation/slot depths from 9750-17455'. On the recent sundry application submitted, perforation depth are listed as 9750-13439'. Please verify which is currently correct for KRU 1J-136. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis(a alaska.gov. 1 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing E Operations Shutdown E Performed: Suspend r Perforate r Other Stimulate r Alter Casing E Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well E Re-enter Susp Well r Other: Marcit Gel Job F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory E 206-154 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r' Service 50-029-23331-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25662,ADL 380058,ADL 25661 KRU 1J-136 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kupurak River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 17507 feet Plugs(measured) 9133 true vertical 3489 feet Junk(measured) Non i - Effective Depth measured 17495 feet Packer(measured) 9023, 9197 NOV 1 5 2016 true vertical 3488 feet (true vertical) 3543, 3568 AOGCC Casing Length Size MD TVD Burst Collapse CONDUCTOR 34" 78 20 121 121 SURFACE 3458 13 5/8 3501 2236 INTERMEDIATE 9688 9 5/8 9730 3631 LINER B-SAND 8298 5 1/2 17495 3528 9750-10240,10173-10178,10558,11056,11371-11821,12136-12635,12989-13439,13752-14246,14561-15020 Perforation depth: Measured depth: 15347-15848,16165-16415,17030-17455 3632-3635,3638-3638,3608-3610,3606-3595,3584-3578,3573-3564,3558-3552,3549-3542,3541-3539 True Vertical Depth: 3543-3555.3536-3527 Tubing(size,grade,MD,and TVD) 4.5, L-80, 9057 MD, 3547 TVD Packers&SSSV(type,MD,and TVD) PACKERS=SL ZXP Liner Top Packer @ 9023 MD and 3543 TVD PACKER=HRD ZXP Liner Top Packer @ 9197 MD and 3568 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE AP Ztyy, Treatment descriptions including volumes used and final pressure: S�!'��NED L 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - Shut-in - - Subsequent to operation - - Shut-in - - 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development r Service F Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil E Gas rWDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ F WAG E GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-458 Contact John Peirce @ 265-6471 Email John.W.Peirce(a'�.conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature .e. Phone:265-6471 Date I- 1 Jl 4/1 /'16 lett Form 10-404 Revised 5/2 15 H7-1— 3!2�/ (?R36M5 � bmit Original OnlykA) ���NOV� i n fu ib 77�-.l7 • • IJ- 136 DTTMSTA JOBTYP SUMMARYOPS 10/11/16 MISC. RU TIORCO/NALCO PUMPING UNIT AND BLEND ACCELERANT FOR CAPACITY MARCIT GEL TREATMENT. JOB IN PROGRESS. SUSTAINMENT 10/12/16 MISC. CAPACITY PUMPED 56 BBL SEAWATER FLUSH FOLLOWED BY LINEAR POLYMER GEL (10,000 PPM CONCENTRATION) TO DETERMINE VOLUME OF MBE FEATURE. PUMPING DOWN 1J-136 TAKING RETURNS FROM PRODUCER 1J-135 AT PTS FLOWBACK UNIT. OVER THE COURSE OF PUMPING, LIQUID RATE AT 1J-135 DROPS GRADUALLY THROUGHOUT JOB TO ALMOST ZERO. WITH 884 BBLS TOTAL PUMPED, A SMALL SLUG OF POLYMER IS PRODUCED AT 1J-135. 1J-135 CONTINUES OCCASIONAL SLUG FLOW OF POLYMER. TURN 1J-136 BACK TO DSO FOR INJECTION, WAIT ON DECISION FOR MARCIT PUMPING PARAMETERS. JOB IN PROGRESS. 10/13/16 PUMPING FREEZE PROTECT, PUMP 3 BBLS METHANOL FLOWLINE, PUMP 44 TRACKING ONLY BBLS DIESEL TUBING. JOB COMPLETE. 11/10/16 MECH RIH WITH HYDRAULIC G-SPEAR AND LATCH ISOLATION SLEEVE IN D- ZONE MOD SAND LEM AT 9,051' CTMD. STRAIGHT PULL ISO SLEEVE FREE, POOH TO SURFACE-- ISOLATION SLEEVE LOOKS GOOD, ALL SEALS IN PLACE. MAKE UP BHA#2, RIH WITH DB-6 PLUG AND SET AT 9,111' CTMD (9,133' RKB). PICK UP PRONG, RIH AND TAG DB-6 PLUG. SET PRONG IN PLUG BODY, PUMP OFF TO RELEASE, AND POOH. JOB COMPLETE. KUP 1J-136 COQ iocoPh1IIN 35 Well Attrib Max Anglit D TD ,. ' ' Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) Aic3,5kd,Inc. Corgcaphidlips 500292333100 WEST SAK INJ 17,507.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MuPopeLaterals-1J-136,11/14/2016 9 20:22 AM SSSV:NIPPLE Last WO: 44.00 1/3/2007 Vertid sdtemebc(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By End Date - - - Last Tag: Rev Reason:PULLED DBPRONG, DB PLUG 8 pproven 9/26/2016 HANGER;37.0 "..)j -- DB NIPPLE SET TYPE 1 ISO asing rings Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 34" 910 Insulated. II CONDUCTOR 34" 20 19.250 42.9 121.0 121.0 94.00 K-55 WELDED _n_• 42.9-1-12 NIPPLE,505.5 Insulatedemus. . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 13 3/8 12.415 42.9 3,501.0 2,236.2 68.00 L-80 Buttress INJECTION,2,211.4 AIL Thread amp Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread talw Window D-Sand 12 10.000 9,090.0 9,100.0 3,552.9 40.00 L-80 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;429-3,501.0 INTERMEDIATE 95/8 8.835 41.4 9,729.7 3,631.0 40.00 L-80 BTC-M 14, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(TVD)... WULen(L..Grade Top Thread SLEEVE-C,0,909.7 D-Sand Liner HH 51/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L-80 BTC-M .-.if Liner Details LOCATOR,9,039.4 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) SEAL ASSY;9,040.5 - 9,082.9 3,550.6 82.48 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 7.660 BTC ISO SLEEVE,9,070.0 -)I( " 9,104.3 3,553.5 82.05'HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 5.020 ti BTC Window DSand;9,090.0- I 9.100.0 "1 9,236.4 3,574.2 80.34 ECP Baker Payzone Packer - 4.930 l I 9,261.5 3,578.4 80.17 XO-reducing '5.5"x4.5" 3.930 PLUG;9,133.0 �� Casing Description I OD(in5) 1/4D (in4)) 1 . Top(ttKB) 1 Set Depth(ftKB) Set Depth(ND)...1 WULen(t...1 GraL80de (TopBTCM Threatl 750 9,196.8 17,495.0 3,528.415.50 MI Liner B-Sand 0Liner Details Iiiii Nominal ID at Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) O D-Sand Liner LEM,9,023.1- ' N ' 9,196.8 3,567.6 80.61 PACKER "HRD"ZXP Liner Top Packer 9-5/8"(7.50"X 8.43") 7.650 9,240.0 ' .' 9,215.4 3,570.7 - 9,219.4 3,571.3 80.48 80.46 NIPPLE "RS"Packoff Seal Nipple 7.00"(6.19"ID x 7.65"0 7.650 11 D-Sand Liner HH,9,082.9- HANGER .FlexLock Liner Hanger 7"x 9-5/8"(6.23"X 8.34") _ 6.230 9,346.0 9,227.2 3,572.6 80.40'XO BUSHING XO Bushing 4.90"ID,7.67"OD 4.900 9,228.9 3,572.9 80.39'SBE 190-47 Casing Seal Bore Ext.4.75"10 x 6.31"OD 4.750 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread INTERMEDIATE;41.4-9,729.7 D-Sand Liner LEM 4 1/2 3.958 9,023.1 9,240.0 3,574.8 12.60 L-80 IBTM _ _ Liner Details Nominal ID SLOTS;9,750.0.10,240.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(') hem Des Com (in) 9,023.1 3,542.7 82.20 PACKER ZXP 7"x 9-5/8"Liner Top Packer,8.43"OD x 7.5"ID. 7.500 (PERF;10,173 0-10,178 SL ZXP liner top packer w/Bi-directional slips.Size 7"x 9-5/8". 9,044.3 3,545.6 82.41 XO-reducing X-Over,7"x 5-1/2"Hydril 563 7.67 OD x 4.92"ID 4.920 9,045.7 3,545.8 82.43 SBR 190-47 Casing Seal Bore Receptacle 6.31"OD x 4.750 4.75"ID SLOTS,10,558.0-11,056.0 1- _ 9,065.4 3,548.3 82.62 X0 Bushing XO Bushing 5-1/2"Hydril 563 x 4-1/2"IBT 6.00"OD 3.940 x 3.94" - 9,070.6 3,549.0 82.67 HANGER PZ LEM above Hook Hanger 7.65"x 3.68"ID.Size: 2.500 4-1/2"x 9-5/8"(150 SLEEVE 11 26 15;3.68"X 18' 2.501D-RECOVERED 7/30-2016) SLOTS,11,371.0-11,821.0 - _ 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65"x 3.68"ID.Size:4 3.688 -1/2"x 9-5/8" 9,133.7 3,557.7 81.47 NIPPLE Camco"DB-6"Nipple,I.D.3.562",IBT.4-1/2"DB 6 3.562 Landing nipple(DB PLUG IN NIPPLE 8 PRONG IN PLUG-3.562"x11'OAL-7/30/2016) 9,236.7 3,574.2 80.34 SEAL Baker Seal Assembly 4-1/2"STL Box up 4.74"seals 3.880 SLOTS,12,136.0-12,635.0 _ = x 3.88"ID.Non-locating seal assembly w/full mule shoe. Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..iSet Depth(TVD)(...Wt(Ib/ft) Grade Top Connection -- TUBING 41/2 3.958 37.8 9,057.5 3,547.3 12.60 L-80 IBT-mod _) _ 9.0. Completion Details SLOTS,12,9873,439.0 _ Nominal ID 1 - Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com _ _ (in) 37.8 HANGER Vetco Gray 11"x 4-1/2"w/4.909"MCA Top Connection 3.958 (Pup 4.36') 505.5 505.5 7.06 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 8,989.7 3,538.1 81.87 SLEEVE-C Baker CMD Sliding Sleeve w/Camco 3.812"'DB'Profile 3.812 SLOTS,13,752.0-14,246.0 _ _ (CLOSED 12/13/11) 9,039.4 3,544.9 82.37 LOCATOR Baker Locator 5.16"0.0. I.D.3.95".GBH-22 Locating 3.958 seal assembly _ _ 9,040.5 3,545.1 82.38 SEAL ASSY Baker 4.74"SBE Seal Assy. _ - 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SLOTS;14,561.0-15,020.0 Top(TVD) Top Incl Top(ftKB) (ftKB) Cl Des Coin Run Date ID(in) 9,070.0 3,548.9' 82.67 ISO SLEEVE TYPE 1 ISO SLEEVE(3.68"x 19') 9/24/2016 2.500 _ 9,133.0 3,557.6 81.49 PLUG (DB PLUG IN NIPPLE 8 PRONG IN PLUG- 7/30/2016 0.000 - - 3.562"x11'OAL-7/30/2016) Perforations&Slots SLOTS,15,347.0-15,848.0 Shot Dens Top(TVD) Btm(TVD) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,750,0 10,240.0 3,632.2 3,634.8 WS B,1J-136 12/10/2006 - 32.0 SLOTS ALL PERFS IN WELLBORE:Alternating SLOTS,16,165.0-16,415.0-4.-4 solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers - - staggered 18 deg,3'non SLOTS,17003.0-17,455.0 _ _ -slotted ends Liner 13-Sand;-Sand;9,196.8-17,495.0 i Ti i .,„ KUP 014111/ 1J-136 ConocoPhillips �: Alaska,Inc. :ono<oPhilhps ••• Mu a Laterals-1J-136,11/14/2016 92023 AM Vr.mal•.'•oc...(rA , HANGER,37.8 11@:: .,•,.•"",,,,,.'''"•"..','''',".." 1 Perforations&Slots CONDUCTOR 34"Insulated; ShotDens _es.... 429-121.0 Top(TVD) Btm(ND) (shots/ NIPPLE;505.5 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 10,173.0 10,178.0' 3,637.9 3,637.7 WS B,1J-136 12/14/2011 6.0 IPERF 31 BIG HOLE INJECTION;2,211 6 10,558.0 11,056.0 3,608.4 3,609.8 WS B,1J-136 12/10/2006 32.0 SLOTS anim 11,371.0 11,821.0 3,606.4 3,594.8 WS B,1J-136 12/10/2006 32.0 SLOTS SURFACE,42.9-3501.0—. SLEEVE-C,8,989.7 12,136.0 12,635.0 3,584.5 3,578.5 WS B,1J-136 12/10/2006 32.0 SLOTS 101, iliri - ■ 12,989.0 13,439.0 3,573.0 3,564.1 WS B,1J-136 12/10/2006 32.0 SLOTS LOCATOR;9,039.4 '•�11 SEAL ASSY;9,040.5 - �' 13,752.0 14,246.0' 3,557.7 3,552.5 WS B,1J-136 12/10/2006 32.0 SLOTS ISO SLEEVE,9,0700 -91( 14,561.0 15,020.0' 3,549.0 3,541.9 WS B,1J-136 12/10/2006 32.0 SLOTS Window 0-Sand;9,090.0- 4 ` I. x i 1 9,100.0 15,347.0 15,848.0 3,541.4 3,539.1 WS B,1J-136 12/10/2006 32.0 SLOTS PLUG,9,133.0 I-) 16,165.0 16,415.0 3,543.1 3,554.6 WS B,1J-136 12/10/2006 32.0 SLOTS la 17,003.0 17,455.0 3,536.5 3,526.7 WS B,1J-136 12/10/2006 32.0 SLOTS D-Sand Liner LEM,9,023.1- Mandrel Inserts 9,240.0 Sl onl D-Sand Liner HH,9,082.9- N Top(ND) Valve Latch Port Size TRO Run 93468 Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com 1 2,211.4 1,907.9 CAMCO KBMG 1 INJ GLV BK-5 0.188 1,450.0 1/28/2007 3:30 8 Notes:General&Safety INTERMEDIATE,41.49,729.7 4 End Date Annotation 1/1/2007 NOTE: MULT-LATERAL WELL,1J-136(B/C-SANDS),1J-136L1(D-SANDS) 4/17/2010 'NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;9,750.0-10,240.0 _ _ 12/15/2011 NOTE PROFILE MODIFICATION-PUMPED 1776 LBS(4MM)CRYSTAL SEAL"B"MBE x@10175 4/28/2016 NOTE MBE TREATMENT DOWN COIL TUBING PUMP 420 BBLS OF SEA WATER WITH 45108 OF 4MM (PERF;10,173.010,178.0 CRYSTAL SEAL 4/28/2016 NOTE:NET PRESSURE INCREASE OF-1000 PSI. SLOTS;10,558.0-11,056.0 SLOTS;11,371 0.11,821.0 — jj]j1 SLOTS 12,136.5-12,635.0 SLOTS;12,989.0-13,439.0 SLOTS;13,752.0-14,246.0 SLOTS,14,561.0-15,020.0 — SLOTS,15,347.0-15,848.0 SLOTS,16,165.0-16.415.0 SLOTS;17,003 0.17,455 Liner B-Sand;9,196.8-17,495.0 • • SOF THE STATE Alaska Oil and Gas 't!' r ofALA s ,A Conservation Commission _ 333 West Seventh Avenue Z' "t Anchorage, Alaska 99501-3572 � GOVERNOR BILL WALKER g Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer sCANNED SCANNEDt b 5 aC ConocoPhillips Alaska,Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sok Oil Pool,KRU 1J-136 Permit to Drill Number: 206-154 Sundry Number: 316-458 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, � f Cathy . Foerster Chair DATED this/edgy of September, 2016. RBDMS '' SEP 1 6 2016 RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION 13 -4--s 7 i/ /r APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations E Fracture Stimulate E Repair Well E Operations Shutdown E Suspend E Perforate E Other Stimulate I- Pull Tubing E Change Approved Progra (! Plug for Red rill fPerforate New Pool E Re-enter Susp Well r Alter Casing r' Other: Marcit Gel Job/1413r F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development E 206-154 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23331-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? none • Will planned perforations require a spacing exception? Yes n No F KRU 1J-136 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25662,ADL 380058,ADL25661 ' Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 17,507' 3,489' ' 17495 + 3488 • 1500 psi 9133 NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 121' 121' Surface 3,458' 13 3/8 3,501' 2,236' Intermediate 9,688' 9 5/8 9,730' 3,631' Liner B Sand 8,298' 5 1/2 17,495' 3,528' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9750-10240, 10173-10178, 3632-3635,3638-3638, 4.500" L-80 9,057' 10558-11056,11371-11821, 3608-3610,3604-3595, 12136-12635,12989-13439, 3584-3578,3573-3564, 13752-14246,14561-15020, 3558-3552,3549-3542, 15347-15848 3541-3539 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-PACKER HRD ZXP LINER TOP PACKER r MD=9197 and 3568 TVD PACKER-PACKER ZXP LINER TOP PACKER ' MD=9023 and 3543 ND SSSV: NONE N/A 12.Attachments: Proposal Summary J Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic E Development E Service F• 14.Estimated Date for 10/1/2016 15.Well Status after proposed work: Commencing Operations: OIL ]I��I�� WINJ F' WDSPL Suspended 16.Verbal Approval: Date: GAS WAG r' GSTOR ESPLUG E Commission Representative: GINJ 1- Op Shutdown fl Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John.W.Peircec conocophillips.com Printed Name John PeirceTitle Sr. gWells �Engineer �J j'� Signature Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test El Mechanical Integrity Test D Location Clearance ❑ Other: tACE c 113/1 V I LFA Post Initial Injection MIT Req'd? Yes 0 No ) l Spacing Exception Required? Yes ❑ No l/ V Subsequent Form Required: V - 4 64 RBDMS k 1/ SEP 1 6 2016 Approved by: P COMMISSIONER APPROVED BY // THE COMMISSION Date: g,./� !jtl 4, ii Fnrm and Form 10-403 ised 11/2015 6eI 4chrf,isvalidfor Wm m the date of approval. Attachments in Duplicate • KUP INJ • 1J-136 CC3h(}CoPhil IpsWell Attributes Max Angle&MD TD AlaskaInc i Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Blm(ftKB) ConorAPlYalps 500292333100 WEST SAK INJ 17,507.0 --- Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date Multiple Laterals-15.136,9/71201610:02:51 AM SSSV:NIPPLE Last WO: 44.00 1/3/2007 • Ventral utrematic,{eclueQ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RECOVERED ISO SLEEVE,SET pproven 9/7/2016 HANGER;37.8 I A�rE DB PLUG&PRONG L. asing rngs Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...W1/Len(I...Grade Top Thread CONDUCTOR 34-Insulated; II CONDUCTOR 34" 20 19.250 42.9 121.0 121.0 94.00 K-55 WELDED sf 42.9-121.O11eR. -"^'�'.-^Insulated NIPPLE;505.5 CasingDescription OD(in) ID(in) Top(ftKB) Set Depth ftKB Set Depth P ( ) p (ftKB) p (ND)...Wt/Len(I...Grade Top Thread MOM I SURFACE 133/8 12.415 42.9 3,501.0 2,236.2 68.00 L-80 Buttress INJECTION;2,211.4 Thread Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Window D-Sand 12 10.000 9,090.0 9,100.0 3,552.9 40.00 L-80 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1 0 INTERMEDIATE 95/8 8.835 41.4 9,729.7 3,631.0 40.00 L-80 BTC-M SURFACE;42.9-3,501.0- ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread D-Sand Liner HH 51/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L-80 BTC-M SLEEVE-C;8,989 Liner Details Mt. Nominal IDLOCATOR;9,039.4 M . Nominal ID ',J_, Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SEAL ASSY;9,040.5 ..'"-=. 9,082.9 3,550.6 82.48 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 7.660 BTC * \ 9,104.3 3,553.5 82.05 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 5.020 window D-Send;9,090.0- ; BTC � 9,100.0 9,236.4 3,574.2 80.34 ECP Baker Payzone Packer 4.930 • 9,261.5 3,578.4 80.17 XO-reducing 5.5"x4.5" 3.930 PLUG;9,133.0 �� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Liner B-Sand 51/2 4.750 9,196.8 17,495.0 3,528.4 15.50 L80 BTCM aolEI Imo` Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) D-Sand Liner LEM;9023.1- 9,196.8 3,567.6 80.61 PACKER "HRD"ZXP Liner To Packer 9-5/8"7.50"X8.43" 7.650 1 9,240.0 P ( ) 9,215.4 3,570.7 80.48 NIPPLE "RS"Packoff Seal Nipple 7.00"(6.19"ID x 7.65"O 7.650 D-Sand Liner HH;9,082.9- 7 9,219.4 3,571.3 80.46 HANGER FlexLock Liner Hanger 7"x 9-5/8"(6.23"X 8.34") 6.230 • 9,346.8 9,227.2 3,572.6 80.40 XO BUSHING XO Bushing 4.90"ID,7.67"OD 4.900 • 9,228.9 3,572.9 80.39 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.31"OD 4.750 INTERMEDIATE;41.4-9,729.7 a _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - - D-Sand Liner LEM 41/2 3.958 9,023.1 9,240.0 3,574.8 12.60 L-80 IBTM Liner Details SLOTS;9,750.0-10,240.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com Nominal ID t 9,023.1 3,542.7 82.20 PACKER ZXP 7"x 9-5/8"Liner Top Packer,8.43"OD x 7.5"ID. 7.500 IPERF;10,na.0-to,ne.o _i [IT SL ZXP liner top packer w/Bi-directional slips.Size 7" f x 9-5/8". 9,044.3 3,545.6 82.41 XO-reducing X-Over,7"x 5-1/2"Hydril 563 7.67 OD x 4.92"ID 4.920 -g 9,045.7 3,545.8 82.43 SBR 190-47 Casing Seal Bore Receptacle 6.31"OD x 4.750 SLOTS;10,5500-11,056.0-= '_ 4.75"ID 9,065.4 3,548.3 82.62 XO Bushing XO Bushing 5-1/2"Hydril 563 x 4-1/2"IBT 6.00"OD 3.940 - x 3.94" 7777 I 9,070.6 3,549.0 82.67 HANGER PZ LEM above Hook Hanger 7.65'x 3.68"ID.Size:4 2.500 -1/2"x 9-5/8"(ISO SLEEVE 11 26 15;3.68"X 18' -/ /- 2.501D-RECOVERED 7/30-2016) SLOTS;11,371.0-11,821.0 _ 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65'x 3.68"ID.Size:4 3.688 -1/2"x 9-5/8" _ 9,133.7 3,557.7 81.47 NIPPLE Camco"DB-6"Nipple,I.D.3.562",IBT.4-1/2"DB 6 3.562 _ Landing nipple(DB PLUG IN NIPPLE&PRONG IN I- PLUG-3.562"x11'OAL-7/30/2016) as 9,236.7 3,574.2 80.34 SEAL Baker Seal Assembly 4-1/2"STL Box up 4.74"seals x 3.880 SLOTS;12,138.0-12,635.0=9 - 3.88"ID.Non-locating seal assembly w/full mule shoe. -) Tubing Strings 3 1 - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection - - TUBING 4 1/2 3.958 37.8 9,057.5 3,547.3 12.60 L-80 IBT-mod _ - Completion Details SLOTS',12,989.0-13,4390 Nominal ID _ - Top(ftKB) Top(ND)(ftKB) Top Mel(") Item Des Com (in) 37.8 HANGER Vetco Gray 11"x 4-1/2"w/4.909"MCA Top Connection 3.958 jj (Pup 4.36') 505.5 505.5 7.06 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 jy 8,989.7 3,538.1 81.87 SLEEVE-C Baker CMD Sliding Sleeve w/Camco 3.812"'DB'Profile 3.812 SLOTS;13,752.0-14,246.0-'- . - (CLOSED 12/13/11) I 9,039.4 3,544.9 82.37 LOCATOR Baker Locator 5.16"O.D. I.D.3.95'.GBH-22 Locating 3.958 seal assembly 9,040.5 3,545.1 82.38 SEAL ASSY Baker 4.74"SBE Seal Assy. 3.880 - - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) - _ _ Top(TVD) Top Incl SLOTS;14,581.0-15,020.0 Top(ftKB) (ftKB) I°) Des Com Run Date ID(in) - - 9,133.0 3,557.6 81.49 PLUG (DB PLUG IN NIPPLE&PRONG IN PLUG- 7/30/2016 0.000 3.562"x11'OAL-7/30/2016) 0 - Perforations&Slots 1 ' Shot Dens SLOTS;15,347.0-15,848.0-• Top IND) Btm(ND) (ehots/f - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,750.0 10,240.0 3,632.2 3,634.8 WS B,1J-136 12/10/2006' 32.0 SLOTS ALL PERFS IN WELLBORE:Altemating solid/slotted pipe- 0.125"x2.5"@ 4 SLOTS;16,165.0-16,415.0-._ circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends _) _ 10,173.0- 10,178.0 3,637.9 3,637.7 WS B,1J-136 '12/14/2011 6.0 IPERF 31 BIG HOLE SLOTS;17,003.0-17,455.0 j "Liner B-Sand;9,196.8-17,495.0s _1 KUP INJ • . 1J-136 Conocof i ip s if sk i>?tt: creroab OMps • Multiple Laterals-1J-136,9/7/2016 10'02'.54 AM Vertical schematic(actual) HANGER;37.8—) -, I('r- Pertorations&Slots Shot CONDUCTOR 34"Insulated; Dens .h/, 42.9-121.01-A1u f,h..J, Top(ND) Btm(ND) (shats/f NIPPLE;505.5 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn AMIE rezt 10,558.0 11,056.0 3,608.4 3,609.8 WS B,1J-136 12/10/2006 32.0 SLOTS INJECTION;2,211.4 I it 11,371.0 11,821.0 3,606.4 3,594.8 WS B,1J-136 12/10/2006 32.0 SLOTS Ma 12,136.0 12,635.0 3,584.5 3,578.5 WS B,1J-136 12/10/2006 32.0 SLOTS SURFACE;42.9-8501.0 SLEEVE-C;8,989.7MIER 12,989.0 13,439.0 3,573.0 3,564.1 WS B,1J-136 12/10/2006 32.0 SLOTS in )• LOCATOR;9,0394 aa 13,752.0 14,246.0 3,557.7 3,552.5 WS B,1J-136 12/10/2006 32.0 SLOTS SEAL ASSY;9540 5 E— 14,561.0 15,020.0 3,549.0 3,541.9 WS B,1J-136 12/10/2006 32.0 SLOTS " ' 15,347.0 15,848.0 3,541.4 3,539.1 WS B,1J-136 12/10/2006 32.0 SLOTS Window D-Sand;9601c968,-,_____,4-•if __ 4 16,165.0 16,415.0 3,543.1 3,554.6 WS B,1J-136 12/10/2006 32.0 SLOTS PLUG;9,1330 ['i" 17,003.0 17,455.0 3,536.5 3,526.7 WS B,1J-136 12/10/2006 32.0 SLOTS -- Mandrel Inserts i 7111 St PE D-Sand Liner LEM;9,023.1- ati 9,240.0 - on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) . Run Date Com 1 2,211.4 1,907.9 CAMCO KBMG 1 INJ GLV BK-5 0.188 1,450.0 1/28/2007 3:30 D-Sand Liner HI-I;9,082.9- f:.xe. 9346.6 Notes:General&Safety End Date Annotation 1/1/2007 NOTE:MULT-LATERAL WELL,1J-136(B/C-SANDS),1J-136L1(D-SANDS) INTERMEDIATE;41.4-9,729.7—J A 4/17/2010 NOTE:View Schematic w/Alaska Schemetic9.0 _ 12/15/2011 NOTE:PROFILE MODIFICATION-PUMPED 1776 LBS(4MM)CRYSTAL SEAL"B"MBE@10175 4/28/2016 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 420 BBLS OF SEA WATER WITH 4510#OF 4 MM SLOTS;9,750.0-10240.0— _ CRYSTAL SEAL 4/28/2016 NOTE:NET PRESSURE INCREASE OF-1000 PSI. (PERF;10,173.0-10,178.0 -7 SLOTS;10,5580-11,056.0 SLOTS:11,371.0-11,821.0 t1-1 SLOTS;12,136.0-12,635.0-- y ." 4441 SLOTS;12,989.0-13,439.0 --.1 SLOTS',13,752 0-14 246 0 _ _ 3 SLOTS;14,561.0-15,0200 j 74 _1 SLOTS;15,347.0-15,848.0—"1E '-' SLOTS;16,165.0-16,415.0 4. SLOTS;17,003.0-17,4550 Liner B-Sand;9,190.8-17,495.0 I C M:1 m1` I—7-7.1 -\::::§ 5-5 mmFXYmo pN Jm_Jao•WN:).;-1::(1)2 624:Nmo7Y>4cuN9028 ao . oUNmp�mz:1 di eL m mmN z0.1 gf e, m OO $ 2 c - p 2 -` W09 `y . `" 0I' ii `oC3 g o `mC am2c aw cOf r po , =aN y c No ❑ _ is o W p L NR m a d ❑ Q 11! ® ® 1 mQ QLQ ' / - o°'8 -❑ ro J5 � En 4 12 _ w >t Ha c8 r" A 8J > ott 0 JJ ?JmNS N 5 CN V2 ; 'LI O. -• V J CO E 75 il C in CU a a m3 a W5 W Bmo ,. .I®2, ila.-0rA ❑ co v m❑ ... F. , xa7. •� ❑ _~ � � (cmMWI _lJJm' C {IH c N aM _ • • 1J-136 to 1J-135 B MBE Retreat with MARCIT Gel Proposal 1J-136 dual-lateral injector with 4-1/2" L-80 tubing was completed December 2006 in West Sak B and D sands. Both laterals have 5-1/2" slotted liners with Constrictors (Swell Packers). A Matrix Bypass Event (MBE) occurred 2/23/10 in 1J-136 B lat to 1J-135 B lat producer. An IPROF of 3/15/11 in 1J-136 showed a B MBE between 10150 - 10680' MD. This interval is mostly covered by 358' of blank liner section. Most PWI was exiting the liner above this blank. On 12/14/11, `big hole' perfs were shot at 10173 - 10178' RKB. On 12/15/11, CT pumped 1776 lbs Crystal Seal (CS) to seal the B MBE. The B lat was then jetted to remove excess Gel and restore PWI to both D & B laterals. This MBE treatment held for a few years. On 8/9/15, an (PROF detected 93% PWI split entering the B lateral. PWI continued until a B MBE occurred 9/19/15. A D Iso-Sly was set 11/26/15. An IPROF run 11/27/15 in the B Lat saw a temperature anomaly at —10650' RKB indicating the presence of a B MBE. On 2/2/16, large hole perfs were shot at 10625 - 10630' RKB. On 4/28/16, 4510 lbs Crystal Seal slurry was pumped to the MBE down coil tubing. This MBE treatment only lasted —3 months. A 7/29/16 (PROF showed the MBE at —10650' RKB was again open. Since 2 Crystal Seal jobs have been pumped and the MBE still remains open, it is proposed that a fullbore MARCIT Gel placement now be full-bore pumped to reseal the B MBE at 10650' RKB. 1J-136 Proposed Procedure: Coil Tubing: 1. RIH & pull the DB Plug set in the DB Nipple at 9133' RKB to open the B lateral for the B MBE treatment. 2. RIH & set an Iso-Sleeve in the D LEM at 9070' RKB to isolate the D lateral. Fullbore Pumping: 3) MIRU Gel Pumping Unit equipment to perform a fullbore MARCIT Gel job. Fullbore pump MARCIT Gel down 4.5" Tubing to the B MBE at 0.5 bpm (target) while monitoring treating pressure response. Inject up to 500 bbls (max target) of accelerated viscosity MARCIT, followed by 12 hrs SI time to build Gel viscosity in the B MBE at 10650' RKB, then resume pumping up to 1000 bbls (max target) of regular MARCIT to complete the MBE treatment. Displace Gel to MBE with Seawater and Diesel FP. Leave well SI for at least 5 days, then return 1J-136 to PWI and monitor offset producer 1J-135 performance. 4) RIH with Jet Swirl Nozzle to jet through excess MARCIT Gel left in the B lateral liner to as deep as possible jetting Seawater. POOH & FP with Diesel. RD. 4) Run a post-treatment memory IPROF log in B lateral to verify that the B MBE is sealed. 5) RIH & pull the D Iso-Sleeve (set 11/26/15) to restore PWI to the D lateral. Return 1J-136 to PWI service to the West Sak B and D sands. JWP 9/6/2016 '2 c,- \5 - 2t1-A65 WELL LOG TRANSMITTAL TAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. /Q/201( K.BENDER To: AOGCC RECEIVED Makana Bender 333 West 7th Avenue AUG•0 8 nib Suite 100 Anchorage, Alaska 99501 AOGCC (907) 793-1225 r� RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 ` Ai;) NOV 0 9 2016 Fax: (907) 245-8952 1) Injection Profile 29-Jul-16 1J-136 Color Log/CD 50-029-23331-70 2) Signed : MAIILLh'a..,(/) t 5_4 ti% Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Di stribution\TransmittalSheets\ConocoPhillips_Transmit.docx • • („{ IT 13r,, PM zil Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday,July 19, 2016 1:59 PM I , bt -71(111c, To: NSK West Sak Prod Engr; 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 Subject: LPP/SSV's returned to service on CPAI 1J wells Jim, The low pressure pilots(LPP) on the following wells were returned to service today, 7/19/16, after injection pressures increased above their pilot settings. 1J-122 (PTD#207-070,207-071,207-072) 11-127 (PTD#206-047, 206-048,206-049) 1J-136 (PTD#206-154, 06-155) 1J-156 (PTD#206-067, 206-068, 206-069) The aforementioned wells have been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No.CO 4066.001." Notification will be sent when the remaining 1J water injector's LPP's are placed back in service. Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ,o , ConocoPhillips Alaska, Inc. Cale`1 J1 Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com From: NSK West Sak Prod Engr Sent:Sunday,July 17, 2016 7:57 AM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com>; Sullivan, Michael <Michael.Sullivan • conoco• i.s.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269 • conoco.hilli.s.com argac, Gary <Gary.Targac@conocophillips.com>; NSK Optimization Engr<n2046 • c•••co.hilli.s.com>; CPF1 DS Operators <n1275@conocophillips.com>; Stanley, Scott M <Scott.M.Stanle • •nocoshill'.s.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI 1J wells Jim, 1 t "S 310 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Ili$ilk Sent: Sunday,July 17, 2016 7:57 AM l 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 iJ wells Jim, The low pressure pilots (LPP) on the following wells were defeated today, 7/17/16, after water injection service was restored to drillsite 1J following the CPF-1 facility shut down. 1J-102 (PTD#206-110, 206-111, 206-112) 1J-118(PTD#206-176,206-177, 206-178) 1J-122 (PTD#207-070, 207-071,207-072) 1J-127 PTD#206-047 206-048 206-049) SCANNED JAI'f 1 2 2U17 1J-136(PTD#206-154 '06-155 1J-154(PTD#205-035, 205-036,205-037) 1J-156(PTD#206-067, 206-068, 206-069) The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety :f Device Log." All injectors are on water injection and stable with building wellhead injection pressures. The AOGCC will be notified when each well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 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 • 1 iAt3Pt� riJ �z6 igfo Regg, James B (DOA) From: Haakinson, David <David.Haakinson@conocophillips.com> Sent: Wednesday,June 22, 2016 1:09 PM 6122(/ To: Regg, James B (DOA) \ Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on well 1J-136 Mr. Regg, The low pressure pilot(LPP) on wel 1J-1367(PTD#206-15 206-155)was returned to service today, 6/22/16, with a pilot setting of 150 psig . The well is currently stabilizing at a we(head injection pressure of 315 psig and rate at 800 BWPD. The well has been removed from the"Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson ���� DECX116 West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 2:6(s--4-o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, May 11, 2016 2:24 PM ` �j ( To: Regg,James B (DOA) �`(1 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; Haakinson, David Subject: Defeated LPP/SSV on well 1J-136 Jim, The low pressure pilot(LPP) on well 1J-136 (PTD#206-154, 206-155)was defeated today, 5/11/16, after the well was brought online after a shut-in period . The well is currently stabilizing at a wellhead injection pressure of 180 psi and rate at 370 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Tyler Hall / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 SCANNED SEP 2 6 2016 Pager: (907) 659-7000 #497 n1638@conocophillips.com � 1 STATE OF ALASKA ANOKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon _.... Plug Perforations P Fracture Stimulate P Pull Tubing P Operations Shutdown P Performed: Suspend I Perforate F Other Stimulate P Alter Casing P Change Approved Program 1- Plug for Redrill laPerforate New Pool I Repair Well F Re-enter Susp Well E Other: Crystal Seal MBE ". 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development Exploratory 206-154 3.Address: 6.API Number: Stratigraphic P Service R- P. O. Box 100360,Anchorage,Alaska 99510 50-029-23331-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25662,380058,25661 KRU 1J-136 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17507 feet Plugs(measured) None true vertical 3489 feet Junk(measured) None Effective Depth measured 17495 feet Packer(measured) 9023, 9197 true vertical 3488 feet (true vertical) 3543, 3568 Casing Length Size MD TVD Burst Collapse CONDUCTOR 34" 78 20 121 121 SURFACE 3458 13 3/8 3501 2236 INTERMEDIATE 9688 9 5/8 9730 3631 RECEIVE LINER B-SAND 8298 9 5/8 17495 3528 MAY 10 2016 AOGCC Perforation depth: Measured depth: 9750-10240, 10558- 11821, 12136- 13439, 13752- 15020, 15347 -15848, 16165- 17455 True Vertical Depth: 3632-3634, 3608-3595, 3584-3564, 3558-3542, 3542-3539, 3543-3527 Tubing(size,grade,MD,and TVD) 4.5, L-80, 9057 MD, 3547 TVD Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER©9023 MD,AND 3543 TVD PACKER-HRD ZXP LINER TOP PACKER©9197 MD AND 3568 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a 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 Shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations R Exploratory P Development P Service (.,. Stratigraphic r 16.Well Status after work: — Copies of Logs and Surveys Run �_m Oil 1 Gas r- WDSPL Printed and Electronic Fracture Stimulation Data I— GSTOR 1— WINJ F WAG P GINJ P SUSP SPLUG , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-766 Contact John Peirce 265-6471 Email John.W.Peirce@conocoohillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature ‘t ,� •ry Phone:265-6471 Date s-7,7 J.(6 Form 10-404 Revised 5/2015 IVTL •57/a //L RBDMS iV MAY 1 0 2016ubmit Original Only S/7U7/4 • 1J- 136 • DTTMS.JOBTYP SUMMARYOPS 2/2/16 MECH RIH WITH HES TCP PERFORATING GUNS, FIRE GUNS FROM TOP SHOT AT ZONE MOD 10,625' TO BOTTOM SHOT AT 10630' CTMD, 6 SPF, PERFORM INJECTIVITY TEST THROUGH CT AT 2 BPM (120 WHP), F/P TBG TO 2500', AT SURFACE IT IS DICOVERED THAT THE INJECTOR CHAINS ARE WORN AND NEED TO BE CHANGED, RIG DOWN CTU FOR INJECTOR SWAP IN DEADHORSE, JOB IN PROGRESS. 2/3/16 MECH TAKE CTU TO DEADHORE TO REPAIR INJECTOR, JOB IN PROGRESS. ZONE MOD 2/4/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/5/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/6/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/7/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 2/8/16 MECH DIAGNOSE INJECTOR FAILURE ISSUE, JOB IN PROGRESS. ZONE MOD 4/28/16 MISC. CAPACITY B&C CTU #1: PERFORM MBE TREATMENT DOWN COIL TUBING WITH NOZZLE SUSTAINMENT PARKED ABOVE SLOTTED LINER AT 9700'. PUMP 420 BBLS OF SEA WATER WITH 4510#OF 4 MM CRYSTAL SEAL. NET PRESSURE INCREASE OF -1000 PSI. WELL LEFT SHUT IN AND FREEZE PROTECTED. WILL RETURN IN THE MORNING FOR FCO. 4/29/16 MISC. CAPACITY B&C CTU #1: PERFORM F&S FILL CLEAN OUT FROM CRYSTAL SEAL TAG AT SUSTAINMENT 9780' TO COIL LOCKUP AT 13645' WITH SLICK SEA WATER AND DJN. WELL LEFT SHUT IN AND FREEZE PROTECTED. TREATMENT COMPLETE. KUP 1J-136 ConocoPhillipsill Well Attribu Max Angl D TD Alaska,Ins, Wellbore APW WI Field Name Wellbore Status ncl(°) MD(5KB) Act Btm(ftKB) W LanocoPhl9tps 500292333100 WEST SAK INJ 17,507.0 °°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple laterals-1J-136,5/4/201611.1138 AM SSSV:NIPPLE Last WO: 44.00 1/3/2007 • Vargcal achsma0c{actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:Crystal Seal Job,SEE NOTES pproven 5/4/2016 ' HANGER;378 -+(. �pi Casing Strings CONDUCTOR 34"Insulated; le Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -A.,-A., P2 .5 CONDUCTOR 34" 20 19.250 42.9 121.0 121.0 94.00 K-55 WELDED NIPPLE;E;55 505.5 Insulated mow WNW Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INJECTION;2,211.4 ", '-' SURFACE 13 3/8 12.415 42.9 3,501.0 2,236.2 68.00 L-80 Buttress Thread llalt Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread vow Window D-Sand 12 10.000 9,090.0 9,100.0 3,552.9 40.00 L-80 Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE;42.&3,501.0-. INTERMEDIATE 95/8 8.835 41.4 9,729.7 3,631.0 40.00 L-80 BTC-M SLEEVE C;8,889.7 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade 'Top Thread D-Sand Liner HH 51/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L-80 BTC-M A 'a- Liner Details LOCATOR;9,039.4 A._-::L Nominal ID SEAL ASSY;9,040.5 Top(ftKB) Top(TVD)(ftKB) Top Incl Cl Item Des Com (in) -11i 9,082.9 3,550.6 82.48 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 7.660 BTC window D-Sana;9,090.5- (,r ► 9,104.3 3,553.5 82.05 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 5.020 9,100.0 I( ;!1 BTC 9,236.4 3,574.2 80.34'ECP Baker Payzone Packer 4.930 - 9,261.5 3,578.4 80.17-XO-reducing 5.5"x4.5" 3.930 =i-- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Liner B-Sand 51/2 4.750 9,196.8 17,495.0 3,528.4 15.50 L80 BTCM m Liner Details D-Send Liner LEM;9,023.1- 8,2400 i. Nominal ID Top(kKB) Top(TVD)(ORB) Top Incl(°) Item Des Com (in) 9,196.8 3,567.6 80.61 PACKER "HRD"ZXP Liner Top Packer 9-5/8"(7.50"X 8.43") 7.650 D-Send Liner HH;9,082.9- ..,., 9,215.4 3,570.7 80.48 NIPPLE "RS"Packoff Seal Nipple 7.00"(6.19"ID x 7.65"0 7.650 9,348.8 9,219.4 3,571.3 80.46 HANGER FlexLock Liner Hanger 7"x 9-5/8"(6.23"X 8.34") 6.230 9,227.2 3,572.6 80.40 XO BUSHING XO Bushing 4.90"ID,7.67"OD 4.900 INTERMEDIATE;41A-9,729.7---....-• - - 9,228.9 3,572.9 80.39 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.31"OD 4.750 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread D-Sand Liner LEM 4 1/2 3.958 9,023.1 9,240.0 3,574.8 12.60 L-80 IBTM SLOTS;9,750.0-10,240.0 = Liner Details - - Nominal ID (PERF;10,173.0-10,178.0 -- Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 9,023.1 3,542.7 82.20 PACKER ZXP 7"x 9-5/8"Liner Top Packer,8.43"OD x 7.5"ID. 7.500 - - SL ZXP liner top packer w/Bi-directional slips.Size - - 7"x 9-5/8". _ 9,044.3 3,545.6 82.41 XO-reducing X-Over,7"x 5-1/2"Hydril 563 7.67 OD x 4.92"ID 4.920 _ SLOTS;10,558.0-11,056.0 9,045.7 3,545.8 82.43 SBR 190-47 Casing Seal Bore Receptacle 6.31"OD x 4.750 - - 4.75"ID 9,065.4 3,548.3 82.62 X0 Bushing XO Bushing 5-1/2"Hydril 563 x 4-1/2"IBT 6.00"OD 3.940 - x 3.94" - - 9,070.6 3,549.0 82.67 HANGER PZ LEM above Hook Hanger 7.65"x 3.68"ID.Size: 2.500 4-1/2"x 9-5/8"SET ISO SLEEVE 11 26 15;3.68"X SLOTS;11,371.0-11,8221.0 - - 18'2.501D - - 9,082.9 3,550.6' 82.48 HANGER PZ LEM Inside Hook Hanger 7.65"x 3.68"ID.Size:4 3.688 -1/2"x 9-5/8" - - 9,133.7 3,557.7 81.47 NIPPLE Camco"DB-6"Nipple,I.D.3.562",IBT.4-1/2"DB 6 3.562 _ _ Landing nipple SLOTS;12,1380-12,635.0 - 9,236.7 3,574.2 80.34 SEAL Baker Seal Assembly 4-1/2"STL Box up 4.74"seals 3.880 x 3.88"ID.Non-locating seal assembly w/full mule shoe. Tubing Strings _ - Tubing Description String Ma... ID(in) Top(RKB) Set Depth(ft..'Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 37.8 9,057.5 3,547.3 12.60 L-80 IBT-mod - - Completion Details SOTS,12,98a0-13,439.0--.--• - Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inti(°) Item Des Com (in) 37.8 HANGER Vetco Gray 11"x 4-1/2"w/4.909"MCA Top Connection 3.958 (Pup 4.36') 505.5 505.5 7.06 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 8,989.7 3,538.1 81.87 SLEEVE-C Baker CMD Sliding Sleeve w/Camco 3.812"'DB'Profile 3.812 SLOTS;13,752.0-14,246.0 - _ (CLOSED 12/13/11) 9,039.4 3,544.9 82.37 LOCATOR Baker Locator 5.16"O.D. I.D.3.95".GBH-22 Locating 3.958 - - seal assembly = 9,040.5 3,545.1 82.38 SEAL ASSY Baker 4.74"SBE Seal Assy. 3.880 - - Perforations&Slots SLOTS;14,581.5-15,020.0 - Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,750.0 10,240.0 3,632.2 3,634.8 WS B,1J-136 12/10/2006 32.0 SLOTS ALL PERFS IN - = WELLBORE:Alternating solid/slotted pipe- - - 0.125"02.5"@ 4 SLOTS;15,347.0-15,848.0 - circumferential adjacent rows,3"centers - - staggered 18 deg,3'non -slotted ends - - 10,173.0 10,178.0 3,637.9 3,637.7 WS B,1J-136 12/14/2011 6.0 IPERF 31 BIG HOLE • SLOTS,16,165.0-16,415.0 - 10,558.0 11,056.0 3,608.4 3,609.8 WS B,1J-136 12/10/2006 32.0 SLOTS 11,371.0 11,821.0 3,606.4 3,594.8 WS B,1J-136 12/10/2006 32.0 SLOTS SLOTS;17,003.D-17,405.0 - 12,136.0 12,635.0 3,584.5 3,578.5 WS B,1J-136 12/10/2006 32.0 SLOTS Line,B-Sand;9,186.8-17,495.0+ KUP a 1J-136 ConocoPhiiiips 0,.. • Alilska..Inc. Co8o4W'hhhp9 """ Multiple Laterals-1J-136,5/4/2016 11:11:38 AM Vermes sche e&toptua0. HANGER;37.6 Top;i ■■ CONDUCTOR 34"Insulated; •I1 i■•' Shot �,, 42.9-121.0 ^ Dens NIPPLE;505.5 Top(TVD) Btm(TVD) (shots/ Top(RKB) Btm(RKB) (RKB) (ftKB) Zone Date IN Type Com INJECTION;2,211.4 12.989.0 13,439.0 3,573.0 3,564.1 WS B,1J-136 1210/2006 32.0 SLOTS 13,752.0 14,246.0 3,557.7 3,552.5 WS B,1J-136 12/10/2006 32.0 SLOTS SURFACE;42.93,501.0ARC 14,561.0 15,020.0 3,549.0 3,541.9 WS B,1J-136 12/10/2006 32.0 SLOTS SLEEVE-C;8,989.7 AllIBI 15,347.0 15,848.0 3,541.4 3,539.1 WS B,1J-136 12/10/2006 32.0 SLOTS iG LOCATOR;9,039.4 _ , 16,165.0 16,415.0 3,543.1 3,554.6 WS B,1J-136 12/10/2006 32.0 SLOTS SEAL ASSY;9,040.5 17,003.0 17,455.0 3,536.5 3,526.7 WS B,1J-136 12/10/2006 32.0 SLOTS s■ whimD-Sand;9,D90.0-_"4 ql 11 it f� 9,100.0 €` 1 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run -- -- N, Top(RKB) (RKB) Make Model OD 5n) Sery Type Type (In) (psi) Run Date Corn MIMI. 1 2,2114 1,907.9 CAMCO KBMG 1 INJ GLV BK-5 0.188 1,450.0 1;28:2007 3:30 II Notes:General&Safety D-Sand Liner LEM;9,023.1- End Date Annotation 9,240.0 WI1/1/2007 NOTE: MULT-LATERAL WELL,1J-136(B/C-SANDS),1J-136L1(D-SANDS) 4/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 D-Send Liner HH;9,032.9-9,346.8 12/15/2011 NOTE:PROFILE MODIFICATION-PUMPED 1776 LBS(4MM)CRYSTAL SEAL"B"MBE@10175 , , 4/28/2016 NOTE:MBE TREATMENT DOWN COIL TUBING PUMP 420 BBLS OF SEA WATER WITH 4510#OF 4MM CRYSTAL SEAL INTERMEDIATE;41.4-9729.7 — — 4/28/2016 NOTE:NET PRESSURE INCREASE OF-1000 PSI. SLOTS;9,750.0-10,240.0 = — IPERF;10,173,0-10,178.0 • SLOTS;10,558.0-11,056.0 SLOTS;11,371.0-11,e21.0 — SLOTS;12,136,0-12,835.0 — SLOTS.12,989.0-13,4390 — .-- -. — I— SLOTS:13,752.0-14.2460 — — SLOTS;14,581.0-15,020.0 — SLOTS;15,347.0-15,848.0 — SLOTS;16,165.0-16,4150 — SLOTS;17,003.0-17,455.0 — • Liner B-Send;9,196.8-17,495.0 e tiOF Tisr � ��/.�s / THE STATE\I Alaska Oil and Gas ALASKAConservation Commission =� 333 West Seventh Avenue *,fit GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o1�ALAS". Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer 5� ,M 1 � L;E ConocoPhillips Alaska, LLC P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, WSAK 1J-136 Permit to Drill Number: 206-154 Sundry Number: 315-766 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, t- t-ct,;(4—\ Cathy P oerster Chair DATED this eday of January, 2016. RBDMSJAN 112016 RECEMO . STATE OF ALASKA • DEL 3 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A00 0 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations Fracture Stimulate Repair Well F Operations Shutdown Suspend - Perforate F Other Stimulate J Pull Tubing 1_ Change Approved Program 1- Plug for Redrill is Perforate New Pool r Re-enter Susp Well E Alter Casing I- Other: crystai SPA'MRF ' F 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska,Inc. - Exploratory E • Development E 206-154 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23331-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order'governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes 1- No 17 / WSAK 1J-136 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25662&380058 1 c256421 Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TV4: j MPSP(psi): Plugs(MD): Junk(MD): l Nl 17,507' 3,489' 17-49S 34 ag 1460 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 121' 121' Surface 3,458' 13 3/8 3,501' 2,236' Intermediate 9,689' 9 5/8 9,730' 3,631' Production Liner 9,197' 5 1/2 17,495' 3,528' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): , 9750-10240, 10558-11821, 3632-3634,3608-3595, 4.5 L-80 9,057' 12136-13439, 13752-15020 3584-3564,3558-3542 15347-15848, 16165-17455 3542-3539,3543-3527 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HRD ZXP LINER TOP PACKER ZXP LINER TOP PACKER ' 9197=MD,3568=TVD 9023=MD, 3543=TVD SSSV: NIPPPLE • 505=MD,505=TVD 12.Attachments: Proposal Summary j Wellbore schematic j 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic 1— Development r Service 17• 14.Estimated Date for 15.Well Status after proposed work: 1/20/2016 Commencing Operations: OIL E WINJ F. WDSPL E Suspended 1- 16.Verbal Approval: Date: GAS 1 WAG E GSTOR r SPLUG E Commission Representative: GINJ 1- Op Shutdown - Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce Email John.W.Peircet conocophillips.com Printed Name John Peirce@265-6471 Title Sr.Wells Engineer ip — 12/2cy/1 S Signature ,ff, Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(5- 7 tit Ce Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes ❑ No Ii,,' Subsequent Form Required: /r'—1-C / APPROVED BY Approved by: � t/ COMMISSIONER THE COMMISSION Date: /_ e... r ubm:t m and Form 10-4o3t se d�z /`6, 0 Rf8afNik alid foriM�ponth1 f7m the date of approval. (/_ nrra�,r�ents in i upih;at l 2016 • • 1J-136 to 1J-135 B MBE Retreatment with Crystal Seal Proposal 1J-136 dual-lateral injector with 4-1/2" L-80 tubing was completed December 2006 in West Sak B and D sands. Both laterals have 5-1/2" slotted liners with Constrictors (Swell Packers). A Matrix Bypass Event (MBE) occurred 2/23/10 in 1J-136 B lat to producer 1J-135 B lat. An IPROF of 3/15/11 in 1J-136 showed a B MBE between 10150' - 10680' MD. This interval is mostly covered by a 358' blank liner section. Most PWI appeared to be exiting the liner above this blank. On 12/14/11, 'big hole' perfs were shot at 10173 - 10178' RKB. On 12/15/11, CT pumped 1776 lbs of Crystal Seal (CS) to seal off the B MBE. The B lat was then cleaned out to remove excess CS and restore PWI to both the D & B laterals. This treatment held a few years. On 8/9/15, an (PROF detected a 93% PWI split entering the B lateral. This showed that a B MBE was again becoming evident. PWI continued until a B MBE occurred 9/19/15. A D Iso-Sly was set 11/26/15, and an IPROF was run on 11/27/15 in the B lateral that found a temperature anomaly at -11650' RKB indicating the likely presence of the B MBE location. It is proposed that CT convey a 2" OD x 5' perf gun to shoot perfs in the B lat at 10625' MD (above a B MBE at -10650' RKB). Next, the B MBE would be sealed with Crystal Seal slurry pumped down CT at -2 bpm to the MBE. After the treatment, 1J-136 will be returned to B sand only PWI to verify that the B MBE has been sealed. After verification that the MBE is sealed, CT will perform an FCO in the B lat and then the D Iso-Sly will be pulled to restore PWI to D lat. 1J-136 Proposed Weliwork Procedure: Coil Tubing: 1. RIH with a 5' OAL x 2" OD Perf gun to shoot 'big hole' perfs, 6 spf, 60 deg ph, in 5.5" slotted liner at 10625 - 10630' RKB. POOH. Verify ASF. 2. Verify 1J-135 is shut-in, then RIH with CT Nozzle BHA to 10610' RKB to pump a Crystal Seal Treatment to the B MBE at -10650' RKB. Park nozzle at 10610' RKB and perform a short SRIT pumping Seawater down CT to determine a preferable constant treating rate, then swap to Crystal Seal Slurry consisting of Seawater with 0.25 ppg of 1,2,4 mm mesh Crystal Seal pumped down CT at an established constant rate (-2 bpm expected). Pump Slurry while slowly POOH with CT until achieving -1000 psi WHIP (to bring WHIP near frac pressure), and then go to Flush pumping 15 bbls of Seawater, followed by Diesel FP to surface, followed by SD. RD. 3) RIH with Jet Swirl Nozzle to jet through excess Crystal Seal left in the B lateral liner. Perform an FCO jetting Seawater to as deep as possible. POOH & FP with Diesel. RD. 4) Run a post-treatment memory IPROF log in B lateral to verify that the B MBE is sealed. 5) RIH & pull the D Iso-Sleeve (set 11/26/15) to restore PWI to the D lateral. Return 1J-136 to PWI service to the West Sak B and D sands. JWP 12/29/2015 • KUP I 1J-136 ConocoPhil ips f Well Attribu Max Angle TD Alaska,Inc". Wellbore APW WI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm IRKS) CormcoPllillips 500292333100 WEST SAK INJ 17,507.0 "." Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MudBp.Laterals-1J-138,12/29/20159:30:24 AM SSSV:NIPPLE Last WO: • 44.00 1/3/2007 • Vedical achamabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET ISO SLEEVE lehallf 12/4/2015 r HANGER;37.8 f 4U.nn.rnr°'.ru Casing Strings Ili CONDUCTOR 34"Insulated; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread _A., 42.9121.0 CONDUCTOR 34" 20- 19.250 42.9 121.0 121.0 94.00 K-55 WELDED NIPPLE;505.5 >•: Insulated . ma 2M//0 Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INJECTION;2,211.4 Z SURFACE 13 3/8 12.415 42.9 3,501.0 2,236.2 68.00 L-80 Buttress 8i Thread Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread ems Window D-Sand 12 10.000 9,090.0 9,100.0 3,552.9 40.00 L-80 II i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;42.9-3,501.0- A INTERMEDIATE 95/8 8.835 41.4 9,729.7 3,631.0 40.00 L-80 BTC-M SLEEVE-C;8,989.7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread D-Sand Liner HH 5 1/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L-80 BTC-M sem. Liner Details LOCATOR;9,039.4 •_.>_,_ Nominal ID SEAL ASSY;9,040.5 - Top(ftKB) Top(TVD)(RKB) Top Incl C) Item Des Com (in) 9,082.9 3,550.6 82.48 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 7.660 BTC • 0-e' r:■ Window D-sand;9,090.0-_,10 jl I i 9,104.3 3,553.5 82.05 HANGER 9.63"x 6.50"PZ Flanged hook hanger,threads 5-1/2" 5.020 9,100.0 �i i'1! 'I BTC I9,236.4 3,574.2 80.34 ECP Baker Payzone Packer 4.930 MI 9,261.5 3,578.4 80.17 XO-reducing 5.5"x4.5" 3.930 10T Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread Liner B-Sand 51/2 4.750 9,196.8 17,495.0 3,528.4 15.50 L80 BTCM ,Pt, Liner Details D-Sand Liner LEM;9,023.1- 9,240.0 i Nominal ID �. Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) • 9,196.8 3,567.6 80.61 PACKER "HRD"ZXP Liner Top Packer 9-5/8"(7.50"X 8.43") 7.650 D-Sand Liner HH;9,0646.82.9- 9,215.4 3,570.7 80.48 NIPPLE "RS"Packoff Seal Nipple 7.00"(6.19"ID x 7.65"0 7.650 9,3 9,219.4 3,571.3 80.46 HANGER FlexLock Liner Hanger 7"x 9-5/8"(6.23"X 8.34") 6.230 9,227.2 3,572.6 80.40 XO BUSHING XO Bushing 4.90"ID,7.67"OD 4.900 INTERMEDIATE;41.4-9,729.7 9,228.9 3,572.9 80.39 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.31"OD 4.750 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread "-- D-Sand Liner LEM 4 1/2 3.958 9,023.1 9,240.0 3,574.8 12.60 L-80 IBTM SLOTS;9,750.0-10,240.0-•- - Liner Details - Nominal ID IPERF;10,173.0-10,178.0----. - Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 9,023.1 3,542.7 82.20 PACKER ZXP 7"x 9-5/8"Liner Top Packer,8.43"OD x 7.5"ID. 7.500 - - SL ZXP liner top packer w/Bi-directional slips.Size - .- T x 9-5/8". 9,044.3 3,545.6 82.41 XO-reducing X-Over,7"x 5-1/2"Hydril 563 7.67 OD x 4.92"ID 4.920 SLOTS;10,558.0-11,058.0 9,045.7 3,545.8' 82.43 SBR 190-47 Casing Seal Bore Receptacle 6.31"OD x 4.750 - - 4.75"ID _ _ 9,065.4 3,548.3 82.62 XO Bushing XO Bushing 5-1/2"Hydric 563 x 4-1/2"IBT 6.00"OD 3.940 x 3.94" - 9,070.6 3,549.0 82.67 HANGER PZ LEM above Hook Hanger 7.65"x 3.68"ID.Size: 2.500 4-1/2"x 9-5/8"SET ISO SLEEVE 11 26 15;3.68"X SLOTS;11,371.0-11,821.0 - - 18'2.50)D - -_ 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65"x 3.68"ID.Size:4 3.688 -1/2"x 9-5/8" - - 9,133.7 3,557.7 81.47 NIPPLE Camco"DB-6"Nipple,I.D.3.562",IBT.4-1/2"DB 6 3.562 Landing nipple SLOTS;12,136.072,635.0 - - 9,236.7 3,574.2 80.34 SEAL Baker Seal Assembly 4-1/2"STL Box up 4.74"seals 3.880 X 3.88"ID.Non-locating seal assembly w/full mule _ shoe. - - Tubing Strings --• - Tubing Description String Ma...ID(In) Top(RKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 37.8 9,057.5 3,547.3 12.60 L-80 IBT-mod - Completion Details SLOTS;12,989.0-13,439.0 - - Nominal ID Top(FRB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 37.8 HANGER Vetco Gray 11"x 4-1/2"w/4.909"MCA Top Connection 3.958 - (Pup 4.36') 505.5 505.5 7.06 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 8,989.7 3,538.1 81.87 SLEEVE-C Baker CMD Sliding Sleeve w/Camco 3.812"'DB'Profile 3.812 SLOTS;13,752.0-14,246.0-A_, (CLOSED 12/13/11) - 9,039.4 3,544.9 82.37 LOCATOR Baker Locator 5.16"0.D. I.D.3.95".GBH-22 Locating 3.958 seal assembly 9,040.5 3,545.1 82.38 SEAL ASSY Baker 4.74"SBE Seal Assy. 3.880 - - Perforations&Slots SLOTS;14,561.0-15,020.0 - Shot Dens Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 9,750.0 10,240.0 3,632.2 3,634.8 WS B,1J-136 12/10/2006 32.0 SLOTS ALL PERFS IN - WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@ 4 SLOTS;15,347.0-15,848.0 - circumferential adjacent rows,3"centers - - staggered 18 deg,3'non _ _ -slotted-ends - - 10,173.0 10,178.0 3,637.9 3,637.7 WS B,1J-136 12/14/2011 6.0 IPERF 31 BIG HOLE SLOTS;16,165.0-16,415.0 _ 10,558.4 11,056.0 3,608.4 3,609.8 WS B,1J-136 12/10/2006 32.0 SLOTS 11,371.0 11,821.0 3,606.4 3,594.8 WS B,1J-136 12/10/2006 32.0 SLOTS SLOTS,17,503.O-17,455.0 - - 12,136.0 12,635.0 3,584.5 3,578.5 WS B,1J-136 12/10/2006 32.0 SLOTS Liner 13-Sand;9,19611-17,495.0,_. KUP I 1J-136 Con©coPhillips411, Alaska.lr1c: Canoco`Phillips Multiple Laterals-1J-136,12/29/2015 9:30:25 AM Oertical schematic(actual) HANGER;37.8 All.,... mimeo e ora ons o CONDUCTOR 34 9-121 0 Shot 42.9-1210 NIPPLE;505.5 _ Dens Top(ND) Btm(TVD) (shots/ AMR Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date R) Type Com INJECTION;2,2114 12,989.0 13,439.0 3,573.0 3,564.1 WS B,1J-136 12/10/2006 32.0 SLOTS 13,752.0-:,\ 14,246.0 3,557.7 3,552.5 WS B,1J-136 12/10/2006 32.0 SLOTS SURFACE;42.9-3,501.0 . 14,561.0 \,15,020.0 3,549.0 3,541.9 WS B,1J-136 12/10/2006 32.0 SLOTS SLEEVE-C;8,989.7 15,347.0 15,848.0 3,541.4 3,539.1 WS B,1J-136 12/10/2006 32.0 SLOTS LOCATOR;9,039.4 >ij - — 16,165.0 16,415.0 3,543.1 3,554.6 WS B,1J-136 12/10/2006 32.0 SLOTS SEAL ASSY;9,040.5 LY' 17,003.0 17,455.0 3,536.5 3,526.7 WS B,1J-136 12/10/2006 32.0 SLOTS ` as■ Window D-Sand;9,090.0-J ) 't 9,100.0 d� Mandrel Inserts St atl 1.1 N Top(TVD) Valve Latch Port Size TRO Run - Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com (�1. 1 2,211.4 1,907.9 CAMCO KBMG 1 INJ GLV BK-5 0.188 1,450.0 1/28/2007 3:30 Notes:General&Safety D-Sand Liner LEM;9,023.1- End Date Annotation 9,240.0 1/1/2007 NOTE:MULT-LATERAL WELL,1J-136(B/C-SANDS),1J-136L1(D-SANDS) 4/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 D-Sand Liner HH;9,082.9- 9,348.8 12/15/2011 NOTE:PROFILE MODIFICATION-PUMPED 1776 LBS(4MM)CRYSTAL SEAL"B"MBE@10175 INTERMEDIATE;41.4-9,729.7 SLOTS;9,750.0.10,240.0- — IPERF;10,173.0-10,178.0 SLOTS;10,558.0-11,058.0 SLOTS;11,371.0-11,821.0 SLOTS;12,136.612,635.0 _. SLOTS;12,909.0-13,439.0_— SLOTS;13,752.0-14,248.0 SLOTS;14,561.0-15,020.0 SLOTS;15,347.0-15,848.0 SLOTS;16,165.0-16,415.0 SLOTS;17,003.0-17,455.0 Liner 8-Sand;9,198.8-17,495.0 2..c.54-ts WELL LOG TRANSM TTAL II• PROACTIVE DIACINOSTIC SERVICES, INC. DATA LOGGED /5/201 M.K.BENDER To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) Injection Profile 27-Nov-15 1J-136 BL/CD 50-029-23331-00 2) mxt4,2Signed : 4-/) 6.6keept Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • �G- 51-1 • tipLt%� WELL LOG TRANSMITTAL# DATA LOGGED r60/2015 i.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC): 1J-136 Run Date: 10/12/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1.1-136 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23311-00 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: / - ALA-474v / ..641'1""C • ZCD33 'L WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 22, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 19AS/2015 Anchorage, Alaska 99501 M.K BENDER RE: Injection Profile : 1J-136 Run Date: 8/9/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1.T-136 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23311-00 Injection Profile 1 Color Log 50-029-23311-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. ;, CAPME° Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ��✓t�� V 6-ei.teat IrTrage Project Well Hi;~t~ar-~ ~ilc Cover Page XI-tV~E This page idr;ntifies ttwse items that were not scanned durir7g 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. ~~~ - 1~" ~- Well History File Identifier Organizing (done) Two-sided III IIIIII II III II III ^ Rescan Needed III IIIIII II II III III RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DI ITAL DATA Diskettes, No. ^ Other, No/Type: ^ Logs of various kinds: NOTES: _. BY: Maria Project Proofing ..---- BY: Maria ~ _` Scanning Prep-a-r-a~-t~ion BY: M/" aria OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) x30= ~~~ + Date: =TOTAL PAGES (Count does not include cover sheet) lsl Production Scanning III IIIIII IIIII II III Stage 1 Page Count from Scanned File: / ~ ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~~ ~ ~ ~ /s/ (~ ~/~ - Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I (III ((III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: Comments about this file: ^ Other:: Date: Date: ~~ aiiiimiiliioiiiii u v~1 ~' o~a„~~~kea miuiiuuiuuii 10/6/2005 Well History File Cover Page.doc KgJJ7-�� � Ph wo1,;- Regg, James B (DOA) From: Haakinson, David [David.Haakinson @conocophillips.com] Sent: Friday, May 31, 2013 9:16 AM J q3'1(3 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Optimization Engr; Seitz, Brian; CPF1&2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; Patterson, Amanda; Stanley, Scott M; CPF1 Prod Engr Subject: Corrected: LPP/SSV returned to normal on 1J-136: 5/31/13 Jim: The low pressure pilot(LPP) on West Sak injector 1J-136 (PTD#206-154 and 206-155) has returned to a normal status today, May 31, 2013, when the wellhead injection pressure increased to a level above 500 psi. This pilot had been defeated yesterday, 5/30/13, and notification was sent in accordance with "Administrative Approval No. CO 406B.001." As of 09:00 hours on 5/31/13, the wellhead pressure is 511 psi at an injection rate of 775 BWPD. Please let me know if you have any questions. Regards, David Haakinson CTD Development Engineer ConocoPhillips Alaska CPF1 Production Office:907-659-7493 Office: 907-263-44 11 1 Cell: 307-660-4999 david.haakinson(a),conocophillips.corn SCANNED K2c� c,T I3c Pit 2040 1 Regg, James B (DOA) From: CPF1 Prod Engr[n1269 @conocophillips.com] 6 36'I(3 Sent: Thursday, May 30, 2013 2:33 PM Qai lc To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Optimization Engr; Seitz, Brian; CPF1&2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr; Patterson, Amanda; Stanley, Scott M; Haakinson, David Subject: LPP/SSV defeated on 1J-136: 5/30/13 Jim, The low pressure pilot(LPP) on injector 1J-136 (PTD#206-154 and 206-155)was defeated today, May 30, 2013, when the wellhead injection pressure fell below 500 psi. Well 1J-136 was returned to injection service today, 5/30/13, after being shut in on May 7, 2013 for surface interference reasons during the rig workover of well 1J-135. `— As of 14:00 hours on 5/30/13, the wellhead pressure is 477 psi at an injection rate of 785 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 4066.001." - Please let me know if you have any questions. Regards, David Haakinson CTD Development Engineer ConocoPhillips Alaska Office: 907-263-4411 1 Cell: 307-660-4999 david.haakinson@),conocophillips.corn SCANNED STATE OF ALASKA KA OIL AND GAS CONSERVATION CO SSION REMIRT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon air w ell Rug Perforations Perforate I Other ./ Set !so-sleeve ❑ P ❑ 9 n C ❑ Alter Casing ❑ Rill Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 206 -154 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service ' 50- 029 - 23331 -00 —` 9g 7. Property Designation (Lease Number): V 8. Well Name and Number: ADL 25662, 380058 - A5 (,? (N 1 1 t \3.1 " 1 J - 1 36 9. Logs (List logs and submit electronic and printed data per 20AAC 5.071): 10. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17507 feet Plugs (measured) 9111 true vertical 3489 feet Junk (measured) None Effective Depth measured 17495 feet Packer (measured) 0 true vertical 3488 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 34 78 20 121 121 0 0 SURFACE 3458 18.187 3501 2236 0 0 INTERMEDIATE 9688 9.625 9730 3631 0 0 LINER B -SAND 8298 9.625 17495 3528 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: solid /slotted liner 9750' 17455' True Vertical Depth: 3632' -3527' RECEIVED NOV 272012 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 9058 MD, 3505 TVD Packers & SSSV (type, MD, and TVD) AOGCC 12. Stimulation or cement squeeze summary: SCANNED FER 2 8 2013 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 4 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 375 870 696 Subsequent to operation 820 1818 612 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r i Development ❑ Service' ,�l Stratigraphic r 16. Well Status after work: Oil ❑ Gas r WDSPL ❑ Daily Report of Well Operations X GSTOR ❑ WINJ C WAG r GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen / Darrell Humphrey Email n11394conocoi hilfips.com Printed Name Darrell Hum hre Title NSK Production Engineering Specialist Signature ' 1 Phone: 659 -7535 Date / i , 2 _5 _ i Rat MS NOV 2 7 20q671 �" /1/ Form 10-404 Revised 12/2012 f Submit Original Only A. r24 /2 • 1J -136 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/27112 RIH WITH GS SPEAR AND LATCH D -SAND TYPE I DIVERTER AT 9077' CTMD. POOH, SWAP TO HYD PRS TOOL. RIH AND LATCH DB PRONG AT 9124' CTMD. ON SURFACE WITH PRONG, RIH AND LATCH DB PLUG, ON SURFACE. TURN WELL OVER TO DSO TO PUT ON INJECTION. I I I I I I i I I I • r / KUP 1J -136 ConocoPhillips a Well Attributes Max Angle & MD TD Alaska. In( ;. Wellbore API /UWI Field Name Well Status Inc! (.) MD (ftKB) Act Btm (ftKB) coran.,Htinips 500292333100 WESTSAK INJ 17,507.0 "-` -' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date • " SSSV: NIPPLE Last WO: 44.00 1/3/2007 Well Confie' Multiple Laterals - 1J -136, 9/16/2012 12'.35'29 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date - - HANGER, 36 8 - -- - - - - -- Last Tag: Rev Reason: SET PLUG & DIVERTER, PULL SLEEVE ninam 9/16/2012 4 fe. CONDUCTOR Casing Strings Casing Description String 0... String ID ... Top (068) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd 34 Insulated, J I CONDUCTOR 34" 20 19.250 42.9 121.0 121.0 94.00 K -55 WELDED 43 -121 Insulated NIPPLE, 505 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 133/8 12.415 42.9 3,501.0 2,236.4 68.00 L -80 Buttress Thread INJECTION, ,,. ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd 2 ammo Window -Sand 12 10.000 9,090.0 9,100.0 3,553.0 40.00 L-80 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd -"' INTERMEDIATE 95/8 8.835 41.4 9,729.7 3,631.2 40.00 L -80 BTC-M SURFACE, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 43 - 3,501 '' ' D - Sand Liner HH 5 1/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L - 80 BTC - M SLEEVE -C. area 8,990 Liner Details Top Depth LOCATOR, (TVD) Top Inc! Nomi... 9,039 - - Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) SEAL A9 0 9,082.9 3,550.6 82.48 HANGER 9.63" x 6.50" PZ Flanged hook hanger, threads 5-1/2" BTC 7.660 9,104.3 3,553.6 82.05 HANGER 9.63" x 6.50" PZ Flanged hook hanger, threads 5-1/2' BTC 5.020 DIVERTER, 8,077 9,236.4 3,574.1 80.06 ECP Baker Payzone Packer 4.930 Window 9,261.5 3,578.4 80.17 X0- reducing 5.5" x4.5" 3.930 D -sand, - 9,090 -9.100 Casing Description !String 0... !String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ' l Liner B - Sand I Str 51/2 Str 4.750 I 9,196.8 17,495.0 3,528.4 I 15.50 I L80 I BTCM ■ PLUG, 9,111 I -1 i Liner Details IIIIIII Top Depth (TVD) Top Inc' Nomi... n.I Top (ftKB) (ftKB) ( °) Item Description Comment ID ('n) l -t 1 9,196.8 3,567.1 79.89 PACKER "HRD" ZXP Liner Top Packer 9-5/8" (7.50" X 8.43 ") 7.650 D -Send Liner ® 9,215.4 3,570.4 79.97 NIPPLE "RS" Packoff Seal Nipple 7.00" (6.19" ID x 7.65" 0 7.650 LEM, 9,023 -9,240 9,219.4 3,571.1 79.99 HANGER FlexLock Liner Hanger 7 "x 9-5/8" (6.23" X 8.34 ") 6.230 D -Send Liner 9,227.2 3,572.5 80.02 X0 BUSHING X0 Bushing 4.90" ID, 7.67" OD 4.900 H 908393447 7 9,228.9 3,572.8 80.03 SBE 190-47 Casing Seal Bore Ext. 4.75 "ID x 6.31" OD 4.750 Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD)... String Wt... String ... String Top Thrd NTERMEDIATE. D - Sand Liner LEM 4 1/2 3.958 9,023.1 9,240.0 3,574.7 12.60 L -80 IBTM 419,730 Liner Details Top Depth (ND) Top Inc( Nomi... 9,750 - 10.240 Top (ftKB) (ftKB) (°) item Description Comment ID (In) 9,023.1 3,543.8 83.66 PACKER ZXP T x 9-5/8" Liner Top Packer ,8.43" OD x 7.5" ID. SL ZXP liner top 7.500 IPERF, packer w/ Bi- directional slips. Size 7' x 9 -5/8 ". 10,173 - 10.178 9,044.3 3,545.9 83.24 XO- reducing X -Over, 7' x 5-1/2" Hydril 563 7.67 OD x 4.92" ID 4.920 9,045.7 3,546.1 83.21 SBR 190-47 Casing Seal Bore Receptacle 6.31" OD x 4.75" ID 4.750 9,065.4 3,548.3 82.83 X0 Bushing X0 Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 6.00" OD x 3.94" 3.940 sl.ors, 9,070.6 3,549.0 82.72 HANGER PZ LEM above Hook Hanger 7.65" x 3.68" ID. Size: 4 -1/2" x 9-5/8 3.960 lossa- 11.058 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65" x 3.68" ID. Size: 4-1/2' x 9-5/8" 3.688 9,133.8 3,557.9 81.47 NIPPLE Camco "DB-6" Nipple, I.D. 3.562 ", IBT. 4-1/2" DB 6 Landing nipple 3.562 9,236.7 3,574.1 80.06 SEAL Baker Seal Assembly 4 -1/2" STL Box up 4.74" seals x 3.88" ID. Non- 3.880 locating seal assembly w/ full mule shoe. SLOTS, T Strin 11,371 - 11.821 9 9 Tubing n Descripti s String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 37.8 9,057.5 3,547.4 12.60 L -80 IBT -mod Completion Details Top Depth (ND) Top Intl Nom'... aLOTS, Top (OKB) (ftKB) ("1 Item Description Comment ID (in) 12.13s- 1z,s35 37.8 37.8 -0.01 HANGER Vetco Gray 11" x 4 -1/2" w/ 4.909" MCA Top Connection (Pup 4.36') 3.958 505.5 505.5 6.75 NIPPLE 4-1/2' Camco "DB -6" Nipple w/ 3.875" No-Go Profile. 3.875 8,989.7 3,541.0 84.32 SLEEVE -C Baker CMD Sliding Sleeve w/ Camco 3.817 "DB' Profile (CLOSED 3.812' 12/13/11) 9,039.4 3,545.4 83.34 LOCATOR Baker Locator 5.16" O.D. I.D. 3.95 ". GBH -22 Locating seal assembly 3.958 sl 439 9,040.5 3,545.5 83.32 SEAL ASSY Baker 4.74" SBE Seal Assy. 3.880 12,989-1 9 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) T op Depth (TVD) Top Intl Comment Run Date ID (in) H Top (ftKB) (ftKB) (1 Description 9,077 3,549.8 82.60 DIVERTER TYPE 1 DIVERTER 8/30/2012 8/30/2012 0.000 sLOrs, 13,752 - 14.248 9,111 3,554.7 81.92 PLUG DB PLUG SLOTS, 14,581- 15.020 Mandrel Details Top Depth Top Port H 1 (ND) Inc( OD Valve Latch Sire TRO Run Stn Top (ftKB) (ftKB) (') Make Model ( in) Sery Type Type (in) (Psi) Run Date Cone... SLOTS, 1 2,211.4 1,906.0 67.11 CAMCO KBMG 1 INJ GLV BK -5 0.188 1,450.0 1/28/2007 15,347 - 15.048 SLOTS, 16,185- 18.415 SLOTS, 17,003 - 17.455 Liner B -Sand, 9,197 - 17.495 TD (1J -136). 17,507 ..... • KUP 1J -136 ConocoPhillips 0 Alaska I19 o _ Co caPlrBtp KB-0rd (ft) Rig Release Date "' 44.00 1/3/2007 Well Conriq. Multiple Laterals - 1J- 136,9/16/201212'3529 PM Schematic - Actual Perforations & Slots Shot CONDUCTOR 34 Insulated, Top (TVD) Btm (TVD) Dena 43.-121 121 al Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (•h••• Type Comment NIPPLE, 505 9,750 10,240 3,632.3 3,636.8 WS B, 1J -136 12/10/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - INJECTION, 0.125'x2.5" @ 4 circumferential emo 2,211 adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 10,173 10,178 3,637.7 3,637.4 WS B, 1J -136 12/14/2011 6.0 IPERF 31 BIG HOLE S 43 __ III 10,558 11,056 3,607.5 3,609.9 WS B, 1J -136 12/10/2006 32.0 SLOTS SLEEVE-C, 11,371 11,821 3,606.4 3,594.9 . WS B, 1J -136 12/10/2006 32.0 SLOTS LOCATOR, 12,136 12,635 3,586.6 3,578.6 WS B, 1J -136 12/10/2006 32.0 SLOTS 9,039 1J -136 12/10/2006 32.0 SLOTS B, SEAL A0 ' 13,439 3 ' 573.0 3,564 2 W S B 9040 0 12989 13,752 14,246 3,557.7 3,552.9 WS B, 1J -136 ' 12/1012006 32.0 SLOTS 3,542.0 WS B 14,561 15,020 3,548.5 3,54 B, 1J -136 12/10/2006 32.0 SLOTS INVERTER, 15,347 15,848 3,541.4 3,539.1 WS B, 1J -136 12/10/2006 32.0 SLOTS Window D -Sand, - 16,165 16,415 3,543.9 3,554.6 WS B, 1J -136 12/10/2006 32.0 SLOTS 9,090 -9,100 1 ` 17,003 17,455 3,536.6 3,526.7 WS B, 1J -136 12/10/2006 32.0 SLOTS PLUG, 9,111 lei Notes: General & Safety jj End Date Annotation MIME 1/1/2007 NOTE: MULT - LATERAL WELL, 1J -136 (B/C- SANDS), 1J -136L1 (D- SANDS) "I II 4/17/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1 ® D -Sand Liner LEM, - - "' 9,0239,240 D -Sand Liner 911, M 9,083 -9,347 NTERMEDIATE, 41 419,730 M. SLOTS, 1 i 9,750 - 10,240 IPERF, 10,173 - 10,178 SLOTS, 10,558 - 11,058 SLOTS, 11,371 - 11,821 SLOTS, 12,138 - 12,835 1 SLOTS, 12,989- 13,439 SLOTS, 13,752- 14,248 1 SLOTS, 14,581 - 15,020 HI SLOTS, 15,347 - 15,848 1 SLOTS, 1 18,185 - 18,415 SLOTS, 1 17,00347,455 Liner BSand, 9,197 - 17,495 TD (1J -138), 17,507 I 0K l'i � I -7-434, pn) i o Regg, James B (DOA) From: CPF1 Prod Engr n1269 conoco hilli s.com 9 C @ p p j Sent: Saturday, October 27, 2012 9:37 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; Patterson, Amanda; CPF1 Prod Engr; NSK Prod Engr Specialist Subject: LPP /SSV defeated on 1J -136 on 10/27/12 Jim: The low pressure pilot (LPP) on injecto 17 -1 PTD# 6 -154 and 206 -155) was defeated on 10/27/2012 when the well was returned to injection service after completing a coil tubing job to pull a plug and open the B Sand. The current wellhead injection pressure is 410 psi and the injection rate is 790 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. thanks, Dana Glessner /David Lagerlef ConocoPhillips Alaska, Inc Kuparuk CPF1 Production Engineer R Qi 9 al 3. p ( NE B � office (907) 659 -7493 Dana .Glessner(a�conocophillips.com 1 STATE OF ALASKA ` ALASKOL AND GAS CONSERVATION COMMI.N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell f Rug Perforations r Stimulate r Other 17 Crystal Seal Tr � t� ent� � r, � . I- Alter Casing r Pull Tubing r Perforate New Pool Waiver r Time Extension I` ,- � - Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206 - 154 3. Address: 6. API Number: Stratigraphic r Service p- P. O. Box 100360, Anchorage, Alaska 99510 - 50 029 - 23331 - 00" 00 7. Property Designatio (Lease Number): r Z 8. Well Name and Number: ADL 25662, 380058 A3 (,p Cp 1 1 1,I 2-- * 1J 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17507 feet Plugs (measured) 9134 true vertical 3489 feet Junk (measured) None Effective Depth measured 17495 feet Packer (measured) 9197, 9023 true vertical 3488 feet (true vertucal) 3567, 3544 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 113 113 SURFACE 3458 13.375 3501 2196 INTERMEDIATE 9688 9.625 9730 3591 LINER B -SAND 8298 5.5 1746t ' % '' 3488 RECEIVED /E JAN 1 1 2012 Perforation depth: Measured depth: solid /slotted liner 9750' - 17455' Alaska Oil & Gas Cans. Commission True Vertical Depth: 3632' -3527' 4necarage Tubing (size, grade, MD, and TVD) 4.5, L - 80, 9058 MD, 3547 TVD Packers & SSSV (type, MD, and TVD) . PACKER - HRD ZXP Liner Top Packer @ 9197 MD and 3567 TVD PACKER - ZXP 7" x 9.625" Liner Top Packer @ 9023 MD and 3544 TVD NIPPLE - Camco DB -6 Nipple @ 505 MD and 505 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 12376 Subsequent to operation 505 13. Attachments 14. Well Class after work: , Copies of Logs and Surveys run Exploratory r Development r Service I- Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR I`"°` WINJ r` WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -328 Contact John Peirce a ( � . 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 1 , jo 1 i2. ,/4. ( S I_i Form 10 -404 Revised 107 • U /• /2 •/Z Submit Original Only 1J -136 Well Work Summary DATE SUMMARY 12/10/11 ATTEMPT TO PULL PRONG A 25' MADE SEVERAL ATTEMPTS UNAB O LATCH UP. JOB IN PROGRESS. 12/11/11 PULLED PRONG AND PLUG FROM 9126' CTMD. (DB PLUG). JOB IN PROGRESS. 12/12/11 SET TYPE 1 ISO SLEEVE WITH 2.5" ID IN D -LEM AT 9090'. WELL PLACED ON INJECTION FOR XSTAL SEAL TREATMENT. 12/13/11 CLOSE CMD @ 8990' CTMD. MIT IA. (TBG = 145 , IA = 280), (15 MIN T = 137, IA = 297), (30 MIN T = 126, IA = 315.) 12/14/11 PERFORATED LINER AT 10,173 - 10,178 CTMD. PUMPED INJECTION TEST AND EXPERIENCED PARTIAL PLUGING EVENT WHILE PUMPING SEAWATER THROUGH CT. SAW PRESSURE BREAK OVER WHILE POOH. FP CT WHILE POOH. NO SIGNS OF DEBRIS IN BHA. JOB IN PROGRESS. 12/15/11 PUMPED TOTAL OF 1,776 LBS OF 4MM MESH CRYSTAL SEAL TO 'B' SAND MBE AT APPROX 10,175' RKB. SAW A GOO �TCATION OF APPROCFMG SCREENOUT WITH 0.20 PPG CRYSTAL SEAL AT NOZZLE. WENT TO 2% KCL FLUSH PRIOR TO SCREENOUT. FREEZE PROTECTED CT. JOB COMPLETE. • s tl (") KUP 1 J -136 ConocoPhillips � •IAtt a ribut es Max Angle & MD TD Alaska Inc. Wellbore API /UWI Field Name Well Status In MD (ttKB) Act Btm (ftKB) c e o. t mps 500292333100 WEST SAK INJ 17,507.0 '" " Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date Well Conae. Multiple Laterals - 1J -136, 1226/2011 9:53,26 AM SSSV: NIPPLE Last WD: 44.00 1/3/2007 __---- - ' schematic - Actual Annotation Depth (ftKB) End Date 'Annotation Last Mod ... End Date "-'T9\NGER :3e - - L ast Tag: Rev Reason: Add Perfs, Close CMD, Set Sleeve ninam 12/28/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR alr CONDUCTOR 34" 20 19.250 42.9 121.0 121.0 94.00 K - 55 WELDED 34 Insulated, 43 -121 ar Insulated NIPPLE, 505 � - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 133/8 12.415 42.9 3,501.0 2,236.4 68.00 L - 80 Buttress Thread INJECTION, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd 2.211 WindowD - Sand 12 10.000 9,090.0 9,100.0 3,553.0 40.00 L - 80 ginge �.: Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd -- INTERMEDIATE 95/8 8.835 41.4 9,729.7 3,631.2 40.00 L BTC - M I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd su D - Sand Liner HH 5 1/2 4.950 9,082.9 9,346.8 3,592.7 15.50 L - 80 BTC - M 3 J. 43 -3,5 -3,801 1 ' SLEEVE-C. 8,990 Liner Details Top Depth LOCATOR. (TVD) Top Incl Noml... 9,039 Top (ftKB) (ftKB) (°) Item Description Comment ID (In) SEAL ASSY, 1j!' 9,082.9 3,550.6 82.48 HANGER 9.63" x 6.50" PZ Flanged hook hanger, threads 5 BTC 7.660 9,040 S 9,104.3 3,553.6 82.05 HANGER 9.63" x 6.50" PZ Flanged hook hanger, threads 5-1/2" BTC 5.020 ISO SLEEVE, 9,236.4 3,574.1 80.06 ECP Baker Payzone Packer 4.930 Window D - Send, - 9,261.5 3,578.4 80.17 X0 reducing 5.5" x4.5" 3.930 9,090 Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd Ill Liner B-Sand 51/2 I 4.750 9,196.8 I 17,495.0 3,528.4 15.50 L80 BTCM PLUG, 9134 Liner Details ' _ I Top Depth lllwll (ND) Top Intl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID ( o - sand Liner 1 9,196.8 3,567.1 79.89 PACKER "HRD" ZXP Liner Top Packer 9-5/8" (7.50" X 8.43 ") 7.650 LEM, 9,215.4 3,570.4 79.97 NIPPLE "RS" Packoff Seal Nipple 7.00" (6.19" ID x 7.65" 0 7.650 9,023 - 9,240 9,219.4 3,571.1 79.99 HANGER FlexLock Liner Hanger 7 "x 9-5/8" (6.23" X 8.34 ") 6.230 D - Sand Liner 4s U 9,227.2 3,572.5 80.02 X0 BUSHING X0 Bushing 4.90" ID, 7.67" OD 4.900 HH, 9083 9,228.9 3,572.8 80.03 SBE 190 Casing Seal Bore Ext. 4.75 "ID x 6.31" OD 4.750 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NTERMEDIATE, D - Sand Liner LEM 4 1/2 3.958 9,023.1 9,240.0 3,574.7 12.60 L IBTM 41-9730 Liner Details Top Depth SLOTS, (TVD) Top Intl Nomi... 9,75x10,240 Top (ftKB) (ftKB) (°) hem Description Comment ID (in) 9,023.1 3,543.8 sass PACKER ZXP T' x 9-5/8" Liner Top Packer ,8.43" OD x 7.5" ID. SL ZXP liner top 7.500 IPERF, packer w/ Bi-directional slips. Size 7" x 9-5/8 ". 10.173 10.178 9,044.3 3,545.9 83.24 XO- reducing X -Over, T' x 5-1/2" Hydril 563 7.67 OD x 4.92" ID 4.920 9,045.7 3,546.1 83.21 SBR 190-47 Casing Seal Bore Receptacle 6.31" OD x 4.75" ID 4.750 1 9,065.4 3,548.3 82.83 X0 Bushing X0 Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 6.00" 00 x 3.94" 3.940 SLOTS 1 0.556 - 11.050 9,070.6 3,549.0 , 82.72 HANGER PZ LEM above Hook Hanger 7.65" x 3.68" ID. Size: 4 -1/2' x 9-5/8" 3.960 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65" x 3.68" ID. Size: 4 -1/2' x 9-5/8" 3.688 9,133.8 333:,885485079...880 557.9 81.47 NIPPLE Camc "06-6" Nipple, I.D 3.562 ", IBT. 4 -1. . /2' ring DB 6 La nding nipple 3.562 9,236.7 3, 574.1 80.06 SEAL Tubing Description String 0... String ID ... Top Baker ttKB Se) al Assembly4 -1/ STL B ox (N up 4.74" seals x 3.88" ID. . Non- g Top 3.880 locating seal assembly w/ full mu le shoe. BLOTS, Tubing Str ings Set Depth (f... Se D ep th D) . St Wt.. String . Strin 11,371 - 11.821 Thrd 1 TUBING 41/2 3.958 37.8 9,057.5 3,547.4 _ 12.60 L -80 IBT -mod Completion Details Top Depth (TVD) Top Intl Norel... SLOTS. Top (ftKB) (ftKB) ( °) Item Description Comment 10 (in) 3.958 12136 12.835 37.8 37.8 - 0.01 HANGER Vetco Gray 11" x 4 -1/2' w/ 4.909" MCA Top Connection (Pup 4.36') 505.5 505.5 6.75 NIPPLE 4 -1/2' Camco "DB -6" Nipple w/ 3.875" No-Go Profile. 3.875 8,989.7 3,541.0 84.32 SLEEVE -C Baker CMD Sliding Sleeve w/ Camco 3,812 ''DB' Profile (CLOSED 3.812 1 12/13/11) 9,039.4 3,545.4 83.34 LOCATOR Baker Locator 5.16" 0.0. I.D. 3.95 ". GBH -22 Locating seal assembly 3.958 SLOTS, 12,989 - 13.439 9,040.5 3,545.5 83.32 SEAL ASSY Baker 4.74" SBE Seal Assy. 3.880 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth 1 (TVD) Top Intl Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) s�ors. 9,098 3,552.7 82.18 ISO SLEEVE ISO SLEEVE SET IN D -LEM 12/12/2011 0.000 13 152- 14.246 9,134 3,557.9 81.47 PLUG SET DB PLUG 8. 1.50 " x 2.92 BAITED w/ 3" GS 6/12/2011 1.825 SLOTS, 14581- 15.020 Mandrel Details . Top Depth Top Port 1 (TVD) Intl OD Valve Latch Size TRO Run Ste Top (ftKB) (ftKB) ( °) Make Model (18) Sery Type Type IiN (psi) Run Date Com... SLOTS, 1 2,211.4 1,906.0 67.11 CAMCO KBMG 1 INJ GLV BK - 5 0.188 1,450.0 1/28/2007 15.347- 15.848 SLOTS, 1 15 165 -1 SLOTS, SLOTS, 1 17,003 - 17.455 Liner 13-Sand. 9,197 - 17.495 TO (1J-138), 17,507 ._ ` KUP • 1J -136 ' ConocoPhillips � $ Alaska. Inc. w KB-Grd (R) Rig Release Date •• Well Conne: MuRON Laterals -1J- 136, 12/28/20119 AM 44.00 1/3/2007 - Schematic - Actual - 1-1ARGER,N Perforations & Slots Shot CONDUCTOR Top ( p ND) Btm (ND) 34•Irrcu -121 43-121 Dens -121 T op (RKB) Btm (ttKB) (RKB) (RKB) Zone Date (oh-- Type Comment NIPPLE, 505 . - 9,750 10,240 3,632.3 3,636.8 WS B, 1J -136 12/10/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - INJECTION, - 0.125"x2.5" @ 4 circumferential 2.211 r , adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends a 10,173 10,178 3,637.7 3,637.4 WSB, 1J -136 12/14/2011 6.0 IPERF 31 BIG HOLE SURFACE. J 10,558 11,056 3,607.5 3,609.9 WSB, 1J -136 12/10/2006 32.0 SLOTS 43 -3,501 SLEEVE C. 8,990 11,371 11,821 3,606.4 3,594.9 WSB, 1J - 136 12/10/2006 32.0 SLOTS LOCATOR, - - 12,136 12,635 3,586.6 3,578.6 WS B, 1J -136 12/10/2006 32.0 SLOTS 9.039 • -- - 12,989 13,439 3,573.0 3,564.2 WS B, 1J -136 12/10/2006 32.0 SLOTS SEAL ASSY. 9.040 13,752 14,246 3,557.7 3,552.9 WSB, 1J -136 12/10/2006 32.0 SLOTS ISO SLEEVE, 14,561 15,020 3,548.5 3,542.0 WSB, 1J -136 12/10/2006 32.0 SLOTS 9,098 window 15,347 15,848 3,541.4 3,539.1 WSB, 1J -136 12/10/2006 32.0 SLOTS D - Sand. II i 9.09049,100 16,165 16,415 3,543.9 3,554.6 WSB, 1J -136 12/10/2006 32.0 SLOTS 17,003 17,455 3,536.6 3,526.7 WS B, 1J -136 12/10/2006 32.0 SLOTS PLUG,9.134 Notes: General & Safety _I End Date Annotation • • II 1/1/2007 NOTE: MULT - LATERAL WELL, 1J -136 (B /C- SANDS), 1J -136L1 (D- SANDS) 1 I' 4/17/2010 NOTE: View Schematic w/ Alaska Schematic9.OREV D -Sand Liner ' LEM, 9,023 -9,240 D -Sand Liner NH, 9,0834,347 4TERMEDIATE, 41 -9,730 SLOTS, 1 i 9,750. 10,240 IPERF, 10,173 - 15,178 SLOTS, 10,558 - 11058 SLOTS, 11,371-11,821 SLOTS 12,136- 12635 SLOTS, 12,989 - 13,439 SLOTS, 13,752-14,246 SLOTS, 14,561- 15,020 SLOTS, 15,347 - 15,848 SLOTS, I 16,165 - 16,415 SLOTS, 17,003- 17,455 Liner B -Sand, 9,197- 17,495 TD (1J -136), 17,507 � r Z °154 Regg, James B (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] (7 I���I i Sent: Tuesday, January 10, 2012 8:09 AM To: 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; Gauer, Jenn L; CPF1 Prod Engr; Jensen, Marc D Subject: LPP /SSV Defeated for 1J -136 on 01/09/2012 Tom and Jim: The low pressure pilot (LPP) on injecto 1J -136 (PTD# 206-154 nd 206 -155) was defeated on 01/09/2012 when the injection pressure fell below 500 PSI whi - • inlec ion. is pressure loss is most likely due to either the failure of a recent CrystalSeal job (Matrix Bypass Event Treatment) or the removal of a CrystalSeal plug in the lateral. This injector had previously been returned to service on January 5th, 2012 after being shut in since December 14, 2011. As of 0800 hrs on 01/10/2012 , wellhead injection pressure is 158 psi; injection rate is 607 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 on either well 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. Ar vio ucy ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907659. C) FEE C 21, IL Mobile - 303.248.6641 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Gauer, Jenn L [Jennifer.L.Gauer @conocophillips.com] Sent: Tuesday, January 10, 2012 8:09 AM To: 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; Gauer, Jenn L; CPF1 Prod Engr; Jensen, Marc D Subject: LPP /SSV Defeated for 1J-136 on 01/09/2012 Tom and Jim: The low pressure pilot (LPP) on injecto 1J -136 (PTD# 206-15and 206 -155) was defeated on 01/09/2012 when the injection pressure fell below 500 PSI while on injection. This pressure loss is most likely due to either the failure of a recent CrystalSeal job (Matrix Bypass Event Treatment) or the removal of a CrystalSeal plug in the lateral. This injector had previously been returned to service on January 5th, 2012 after being shut in since December 14, 2011. As of 0800 hrs on 01/10/2012 , wellhead injection pressure is 158 psi; injection rate is 607 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 on either well 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. �ir.✓ic-Y- ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907659.' . 9 ' `` Mobile - 303.248.6641 1/10/2012 f2(.( i7 - 3 PTb 7,) b /5“, Regg, James B (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Sunday, January 08, 2012 2:50 PM To: 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; Gauer, Jenn L; Jensen, Marc D Subject: LPP /SSV Returned to Service for 1J -136 on 01/07/2012 Tom / Jim, The low pressure pilot (LPP) on injecto 1J -136 PTD# 206 -15- and 206 -155)) was returned to service late on 01/07/2012 after the wellhead injection pressure sty •ilized above t e s- ing of the low pressure pilot. Current wellhead pressure is 591 psig; injection rate is 537 bwpd. This pilot had been defeated on 01/06/2012 in accordance with "Administrative Approval No. CO 406B.001." The LPP on injector 1J -176 (PTD# 207 -099) remains defeated; it is currently operating at a wellhead pressure of 463 psi with an injection rate of 1186 bwpd. We will notify you when it is returned to service. Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers 542 61146° Eb n1269a,conocophillips.com 659 -7493 pager 659 -7000 765 1, Marc D y, January 05, 2012 4:09 PM inder@alaska.gov'; 'jim.regg @alaska.gov' 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; Gauer, Jenn L; CPF1 Prod Engr PP /SSV Defeated for 13-136 on 01/05/2012 Tom and Jim: The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) was defeated on 01/05/2012 when the injector was returned to service after being shut in since December 14, 2011. As of 1600 hrs on 01/05/2012 , wellhead injection pressure is 390 psi; injection rate is 530 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 on either well 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. Marc Jensen West Sak Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 907 - 265 -6573 1 marc .d.iensen(,conocophillips.com 1 • Page 1 of 1 Maunder, Thomas E (DOA) From: Jensen, Marc D [Marc.D.Jensen @conocophillips.com] Sent: Thursday, January 05, 2012 4:09 PM To: 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; Gauer, Jenn L; CPF1 Prod Engr Subject: LPP /SSV Defeated for 1J -136 on 01/05/2012 Tom and Jim: The low pressure pilot (LPP) on injecto' 1J -136 (PTD# 206 -15 -nd 206 -155) was defeated on 01/05/2012 when the injector was returned to service after being s ut in since December 14, 2011. As of 1600 hrs on 01/05/2012 , wellhead injection pressure is 390 psi; injection rate is 530 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 on either well 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. • Marc Jensen West Sak Drilisite Petroleum Engineer ConocoPhillips Alaska, Inc. .,; 907 - 265 -6573 1 marc.d.jensen @conocophillips.com FEE t 1/6/2012 • • 0[F A[LAsIA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. (t P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J -136 Sundry Number: 311 -328 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Da 'el T. Seamount, Jr. Chair DATED this day of October, 2011. Encl. STATE OF ALASKA ,iiECEJVE ALASKAND GAS CONSERVATION COMMISSIO OCT 2 5 201 � A APPLIC FOR SUNDRY APPROVALS 4106 . �o 20 AAC 25.280 Ataska nil R G Gas Cans_ Comm 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Chang�Approy dd i Program r` Suspend r Rug Perforations r Perforate r Pull Tubing r" / ail ► ►ttGGii�1 xtension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: Crystal Seal Treatm 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 206 - 154 • 3. Address: 6. API Number: Stratigraphic r Service 17 • P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23331 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes if No I 1J :136 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25662, 380058 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): 17507 • 3489 • 17495' 3488' 9134' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 113' 113' SURFACE 3458 13.375" 3501' 2196' INTERMEDIATE 9688 9.625 9730' 3591' LINER B -SAND 8298 5.5" 17495' 3488' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): solid /slotted liner from 9750'- 17455' 3632' -3527' 4.5 L -80 9058 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - ZXP LINER TOP PKR MD= 9023 TVD= 3544 PACKER - HRD ZXP LINER TOP PACKER MD= 9197 TVD= 3567 NIPPLE - 4 -1/2" Camco "DB -6" Nipple w/ 3.875" No -Go Profile. MD= 505 TVD= 505 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/1/2011 Oil r` Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ 17 • GINJ r WAG r Abandoned [ Commission Representative: GSTOR r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce © 265 -6471 Printed Name John Peirce Title: Wells Engineer Phone: 265 -6471 Date �,(� /24 %L . Commission Use Only Sundry Number: 31 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: ` 4/041 / APPROVED BY Approved by: ` / `" /2" COMMISSIONER THE COMMISSION Date: // .. r Form 10 -403 DMS01tr 2 6 i0 ' /° • 2-G'!" ®R 1 G 1 N A L Submit in uplicate :c—i KUP • 1J 136 l UPS s l Attributes_ Wgl COnOCO _ Max Angle & MD TI) Alas.'.£i ' Y .� f' r y W Ilbo a API/UWI Field Name 'Well Status Inc/ r) IMD (ftKB) Act Bim (ftKB) 4 ,., It , t , 5002 _WEST SAK INJ I 17,5070 Comment H2S(ppm) Date Annotation End Date KB (ft) Rig Release Date w et C�lhT,M # --1J .b1 SSSV NIPPLE Last WO: kI 4400 1/3/2007 Schtthotic Aayat , , Annotati 11 on Depth (ftKB) I End Date 1Annotation g Last Mod 11 _. .I End Date RANC>:R, 3a r Last Ta t Rev Reason: Pull Iso Sleeve, Set Prong &Plc I l rnnam_ l 6/15/20 Casing Strings " . Casing Description String 0... String ID ... Top (ftKB) Set Depth (1.. Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR - CONDUCTOR 34" 20 19250 42.9 121 - 0 121.0 94.00 K - 55 WELDED 34 Insulated 43 - 121 Insulated _ �_ NIPPLE, 505 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f.�Set Depth (ND) String Wt... String ... String Top Thrd yam ,, SURFACE 13 3/8 12.415 42.9 3,501.0 2,236.4 _ 68 00 L - 80 Buttress Thread INJECTION,_ a•ua:'.'. Casi Description Siring 0... String ID... Top B Set Depth f.. s et De (TVD) - String Wt... String String T Thrd 2.211 ' : :. do pndn 9 9 9 ,09 ) fop ( ,5 .0 )... g g... rig op Window DSand 12 10.000 9,090.0 9,100.0 3,553.0 40.00 L MOW Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd INTERMEDIATE 9 5/8 8.835 41.4 9,729.7 3,631.2 40.00 L BTC - I 11 j( C ng Description String 0... String ID ... Top (ftKB) Set Depth (0... Sat Depth MD) String Wt... String ._ String Top Thrd SURFACE, ( DSand Liner HH 5 1/2 4.950 9082.9 9,346.8 3,592.7 15.50 L BTC - M 433,501 SLEEVE -O. iPo�;�: ".a; j„ 8,990 1111 Liner Details 5 _ . Top Depth - LOCATOR, IWVO) Top Inc! Nomi... 9,039 .._.. a'r, Top(fIKB) (NKB) () Item Desor!• Ton . -._ CammeM ID (in) SEAL ASSY. - 9,082.9 3,550.6 HANGER 9.63 x 6 50" PZ Flanged hook hanger, threads 5 - 1/2" BTC 7.660 9,040 9,104.3 3,553.6 82.05 HANGER 9.63 x 6 50" PZ Flanged hook hanger, threads 5 -1/2" BTC 5.020 I 9,236.4 3,574.1 80.06 ECP Baker Payzone Packer 4.930 Window Dsand � _t - : 9,261.5 3,578.4 80.17 XO reducing 5.5" x4 5" 3.930 9,090 - 9,100 Casing Description String 0... String ID .. ` (ftKB) 'Set Depth (f Set Depth (ND) . IStr g Wt... String ... IString Top Thrd I I Liner B - Sand 5 1/2 ii 4 750 19 196 8 17,495.0 3,528 4 15 50 L80 BTCM PLUG, 9,134 II LinerDetails -h - Top Depth • .. -_ -. (ND) Top Intl Nomi... "NM" T 011(B) (ftKB) (") Item Dscription Comment ID (in) 9,196.8 3,567.1 79.89 PACKER "HRD" ZXP Liner Top Packer 95/8" (7.50" X 8.43 ") 7.650 D � LEM, -- - "�'�' 9,21574 3,570.4 79.97 NIPPLE "RS" Packott Seal Nipple 7.00" (6.19" ID x 7.65" 0 7.650 9,023 - 9,240 9,219.4 3,571.1 79.99 HANGER FlexLock Liner Hanger 7"x 9 -5/8" (6.23" X 8 34") 6.230 D -Sane Leer 9,227.2 3,572.5 80.02 X0 BUSHING X0 Bushing 4.90" ID, 7.67" OD 4.900 9,083 - 9,347 9,228.9 3,572.8 80.03 SBE 190-47 Casing Seal Bore Ext 4.75 "I0 x 6.31" 013 4.750 1 Casing Description !String 0... !String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NTERMEDIATE, D Liner LEM , 4 1/2 I 3.958 9,023.1 I 9,240.0 I 3,574.7 j 12 60 L IBTM 41 -9,730 - Liner Details .ae WO .n Top Depth SLOTS. °P - ww (ND) Top Ind Nomi... 9,750.10,240 wilf = Top OMB) (1188) _. (") Item Descri•tion Comment ID (in) - 9,023.1 3,543.8 83.66 PACKER ZXP 7" x 9-5/8" Liner Top Packer ,8.43" 00 x 7.5" ID. SL ZXP liner top 7.500 tos sx. packer w/ Bi- directional slips. Size 7" x 9 -5/8". "" °` 9,044.3 3,545.9 8324 X0- reducing X -Over, 7" x 5-1/2" Hydril 563 7.67 OD x 4.92" ID 4.920 SI. MAO 9,045.7 3,546.1 83.21 SBR 190-47 Casing Seal Bore Receptacle 6.31" OD x 4.75" ID 4.750 SLOTS c 9,065.4 3,548.3 82 -83 X0 Bushing X0 Bushing 5 -1/2" Hydril 563 x 4-1/2" IBT 6.00" OD x 3.94" 3.940 w 10,558 wo. 9,070.6 3,549.0 82.72 HANGER PZ LEM above Hook Hanger 7.65" x 3.68" ID. Size: 4-1/2" x 9-5/8" 3.960 Zre 3 9,082.9 3,550.6 82.48 HANGER PZ LEM Inside Hook Hanger 7.65" x 3.68" ID. Size: 4-1/2" x 9 -5/8" 3.688 .. 9,133.8 3,557.9 81 47 NIPPLE Camco "DB -6" Nipple, ID_ 3 562", IBT. 4 -1/2" DB 6 Landing nipple 3.562 o. 9,236.7 3,574.1 80.06 SEAL Baker Seal Assembly 4 -1/2" STL Box up 4.74" seals x 3.88" ID. Non- 3.880 iwir locating seal assembly w/ full mule shoe. I w x.. a.. SLOTS. a °•^' 11371 - 11.821 -w' Je ,y.. Tubing Strings ua •w Tubing Description String 0 String ID... Top (ftKB) Set Depth (1 . Set Depth (ND) ... String Wt... Strng .'String Top Thrd TUBING 41/2 3.958 3) .8 9,057.5 3,547.4 12.60 L -80 IBT -mod Completion Details Top Depth SLOTS, ---.t- ow. (TVD) Top Intl Komi... 12,136 - 12.635 Top (MB) HUM) (") two Doowiptioo Comment ID(in) E 37.8 37.8 -0.01 HANGER Vetco Gray 11" x 4-1/2" w/ 4.909" MCA Top Connection (Pup 4.36') 3.958 :"' 505.5 505.5 6.75 NIPPLE 4-1/2" Camco "DB -6" Nipple wi 3 875" No-Go Profile. 3.875 _ 8,989.7 3,541.0 8422 SLEEVE-0 Baker4.5"CMD Sliding Sleeve w/ Camco 3 812 "'DB' Profile(OPEN) 3.812 - ,r..: -» 9,039.4 3,545.4 83.34 LOCATOR Baker Locator 5.16" 0.0 LD. 3.95". GBH 22 Locating seal assembly 3.958 SLOTS, X : .a 9040.5 3,545.5 83.32 SEAL ASSY Baker 4.74" SBE Seal Assy. 3.880 12,989 - 13.439 I "r9 aappa. Other In Hole ireline retrievable plugs, valves, pumps, fish, etc. ,' Y Top Depth W. " " ' e (TVD) Top Inc! Wo I T 0188) (ftKB) - C1 Description Comment Run Date ID (in) me W• • 3,557.9 81.47 PLUG SET DB PLUG & 1.50 "x 2.92' BAITED w/ 3" GS 6/12/2011 1.825 , ..y am - SLOTS, , 4 1 13,752-14,246 w x°w iii mos SLOTS. 14,561 - 15.020 +x* -dm • 1 Mandrel Details -._ .__ Top Depth Top - Port (TVD) Intl OD Valve Latch Si.. 0120 Run Stn Top (ftKB) (ftKB) ( ") Make Model (in) set. TYpe Type (1.) (poi) Run Date Cam... SLOTS, 1 1 2,211.4 1,906.0 67.11 CAMCO KBMG 1 INJ GLV BK - 5 0.188 1,450.0 1/28/2007 15,347- 15.846 p . - ▪ I SLOTS, 1 ra 16,165- 16.415 we V16 ▪ Ew: SLOTS, " 17,003 - 17.455 Mr" a Lin&B -Sand, X i 8 1'4 9.197 - 17.495 TD (1J-136), J L 1 17,507 . ., • KU P • 1J-136 �, 4, � rt b- y,rFi C�i�Plillips .mV. , ,,a: p, l • KB-Card (ft) Rig Release Date -' _ 44 00 1!3/2007 ent+ama6a- Ae4,er ..._ - - HANGER, 38 ., Perforations & Slots CONDUCTOR 43 -121. Tap (ftK6) Earn (ftKB) (HKB) MKS) Zone Top (TVD) Ban (TVD) Shot Dens 34' I Date (oh... Continent Conent 43 -t 21 NIPPLE, 505 - 9,750 10,240 3,632.3 3,636.8 WS B, 1J 12/10/2006 32.0 SLOTS ALL PERFS IN WELLBORE: K F.i Alternating solid/slotted pipe - INJECTION, ..+tea, 0.125 "x2.5" @) 4 circumferential 2,211 :... adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 10,558 11,056 3,607.5 3,609.9 WS B, 11-136 12/10/2006 32.0 SLOTS SURFACE, 11,371 11,821 3,606.4 3,594.9 WS B, 1J -136 12/10/2006 32.0 SLOTS 43 - 3,501 � SLEEVE - O, " 12,136 12,635 3,586.6 3,578.6 WS B, 1J - 136 12/102006 32.0 SLOTS 8,890 e> 12,989 13,439 3,573.0 3,564.2 WS 8, 14 12/10/2006 32.0 SLOTS LOCATOR, � 'B� . - ' 9,039, 13,752 14,246 3,557.7 3,552.9 WS B, 1J - 136 12/10/2006 32.0 SLOTS SEAL ASSV. .. - 9,040 - -- 14,561 15,020 3,548.5 3,542.0 WS B, 14-136 12/10/2006 32.0 SLOTS 15,347 15,848 3,541.4 3,539.1 WS B, 1J -136 12/10/2006 32.0 SLOTS 16,165 16,415 3,543.9 3,554.6 WS B, 14-136 12/10/2006 32.0 SLOTS Window -- D - Sand, 0 17,003 17,455 3,536.6 3,526.7 WS B, 1J - 136 12/10/2006 32.0 SLOTS 9,090 -9,100 Notes: General & Safety 1 End Date Annotation PLUG,9,134 - /1 N ��' 1/1/2007 NOTE MULL - LATERAL WELL, 1J-136 (B/CSANDS), 1J -136L1 (D- SANDS) • r;- 4/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0REV Harm I D -Sane Liner L2 --- 9,0239,240 40 D -Sand Liner FM, . 9,083 -9,347 • VTERMEDIATE, 41 -9,730 OW Imo we fen SLOTS, 9,750-10,240 _ aw wo • woo too ow SLOTS, .A.;. - 10,558 - 11,056 w`' Mw wm SLOTS. ._.__ 11,371 - 11,821 wow ow .1 i Z 4. 4. SLOTS. _, 12,136 - 12,635 wo wo- SLOTS, p 12,989 - 13,439 '°° ow • we `alt ... 4 . we .' SLOTS. - _. ,- 13,752- 14,246 11 wow SLOTS, C 14561- 15,020 rows vw wo wo SLOTS, ow =m" 15,347- 15,848 i = 1 SLOTS. 0 OW 16,165-16,415 ww1 1 It. SLOTS, 17,003- 17,455 7 - *a Liner 8-Sand,' 9,197 - 17,495 - 0 TD (1J- 136), i i 17,507 J a.. • • 1J -136 to 1J -135 MBE Treatment A matrix bypass event (MBE) occurred 2/23/10 in 1J-136 with breakthrough to 1J-135 producer. A 3/15/11 IPROF in 1J -136 found a 'heel' MBE in the area between 10150 to 10680' RKB in an interval covered mostly by a 358' section of blank 5.5" liner. Most PWI appears to exiting a slotted liner joint just above the top of this long blank section. Halliburton CrystalSeal is intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is a water swellable dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal swells to 400 times original size by hydrating and absorbing water. Due to swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate acceptance of injection. Procedure: / (t A/VOL) Coil Tubing: `!►to 1) Pull the isolation Plug from the 1J-136 at 9134' MD to re -open access to the B lateral. 2) Set a 2.75" min ID Isolation Sleeve inghe D LEM at 9100' MD to isolate 1J -136L1 D lateral. cv 3) RIH with BHA on 2 "coil tubing consisting from bottom to top of 5' OAL x 2" OD TCP Perf Gun, a 2 -1/8" OD closed Circ -Sub, and hydraulic disconnect. Park perf gun to fire 6 spf large hole charges at +/ -10173 - 10178' RKB in a 5.5" slotted liner joint just above the 'heel' MBE located behind the 358' blank liner section. Drop a ball to fire the gun, then RIH —5' with coil to spot the Circ -Sub over the perf interval. Drop ball #2 to shift the Circ -Sub open, then proceed to pump a Crystal Seal treatment through the Circ -Sub and perfs to seal off the MBE. Pump as follows: a) Seawater down coil at 2.0 bpm until ready to slurry. Hold 2.0 bpm constant throughout treatment through Flush (step g) to monitor treating pressure change at constant rate. When crew is ready to start mixing Crystal Seal slurry, swap from Seawater to 2% KCI and pump, --- b) 2% KCI Water with 0.05 ppg CrystalSeal (4 mm mesh, all stages) down coil. Each stage volume is decided during pumping based on treating pressure response seen during the stage. During each stage, check PU weight to ensure Crystal Seal buildup around BHA is not becoming a threat to POOH. When called, swap to subsequent sequential stages as follows: c) 2% KCI Water w/0.10 ppg CrystalSeal down CT, or Flush (step g) should we see screen out. d) 2% KCI Water w /0.15 ppg CrystalSeal down CT, or Flush should we see screen out. e) 2% KCI Water w /0.20 ppg CrystalSeal down CT, or Flush should we see screen out. f) 2% KCI Water w/0.25 ppg CrystalSeal down CT, or Flush should we see screen out. g) If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of ,/ Seawater Flush to displace Crystal Seal Slurry from coil to the well while POOH. If screenout indication has not been seen prior to Flush, leave CT x Tbg annulus shut -in and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to MBE while POOH with CT to D LEM, then swap to 73 bbls of Diesel FP down coil, followed by 1 CT volume ( -40 bbls) of Diesel to displace Diesel FP to tubing and FP CT, followed by SD. RD CTU. Wait a minimum of 6 hrs before returning 1J -136 to PWI for post- treatment injectivity evaluation. Page 1 of 1 • • Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Wednesday, September 28, 2011 4:46 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV Returned to Service on 1J -136 Tom / Jim, The low pressure pilot (LPP) on injector 1 - D# - and 206 -155)) was returned to service on 9/28/2011 after the wellhead injection pressure sta ve the setting of the low pressure pilot. Current wellhead pressure is 628 psig; injection rate is 684 bwpd. This pilot had been defeated on 9/23/2011 in accordance with "Administrative Approval No. CO 406B.001." The LPP on injector 1J -176 (PTD# 207 -099) remains defeated and we will notify you when it is returned to service. Please let me know if you have any questions. Jenn Gauer Work - 907.265.6782 Mobile - 303.248.6641 } a r j ,t 4a4�; rk a I ' From: CPF1 Prod Engr Sent: Friday, September 23, 2011 9:44 AM To: Gauer, Jenn L; '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 Subject: LPP /SSV defeated on 13-136 & 13-176 Tom and Jim The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) was defeated on 09/23/2011 when the injector was returned to service after being shut in since July 14, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 383 psi; injection rate is 906 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." Also, the low pressure pilot (LPP) on injector 1J -176 (PTD# 207 -099) was defeated on 09/23/2011 when the injector was returned to service after being shut in since August 1, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 174 psi; injection rate is 313 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 on either well 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. Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269 @conocophillips.com 907 - 659 -7493 pager 907 - 659 -7000 #765 9/29/2011 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 23, 2011 9:44 AM To: Gauer, Jenn L; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV defeated on 1J -136 & 1J -176 Tom and Jim The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) was defeated on 09/23/2011 when the injector was returned to service after being shut in since July 14, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 383 psi; injection rate is 906 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." Also, the low pressure pilot (LPP) on injector 1J -176 (PTD# 207 -099) was defeated on 09/23/2011 when the injector was returned to service after being shut in since August 1, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 174 psi; injection rate is 313 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 on either well 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. Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269 @conocophillips.com 907 - 659 -7493 pager 907 - 659 -7000 #765 9/23/2011 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Wednesday, June 22, 2011 5:19 PM To: Maunder, Thomas E (DOA) Subject: FW: LPP /SSV Returned to Service on 1J -136 - 22- JUNE -2011 Tom, 1 tried to send this to you today and it was returned to me. Just trying again with a different address. Jenn Gauer O IJ V 3 �0 Work - 907.265.6782 i (. Mobile - 303.248.6641 t}} {{ r r �. + i J iiiiikj Jt.l L 1 i��- . # From: Gauer, Jenn L Sent: Wednesday, June 22, 2011 5:03 PM To: CPF1 Prod Engr; 'jim.regg @alaska.gov'; 'Maunder, Thomas E (DOA) ' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV Returned to Service on 13-136 - 22- JUNE -2011 Tom / Jim, The low pressure pilot (LPP) on 1J-136 (206 -154 and 206 -155) was returned to service on 6/22/2011 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure 557psig; injection rate is 641 bwpd. This pilot had been defeated on 3/6/2011 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Jenn Gauer Work - 907.265.6782 Mobile - 303.248.6641 From: CPF1 Prod Engr Sent: •day, March 06, 2011 10:13 PM To: 'jim.re. • ^alaska.gov'; 'Maunder, Thomas E (DOA) ' Cc: CPF1 DS Lea. -chs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gauer, Jenn L; NSK West Sak Prod Engr; Hutchers• -, ark R; NSK Pro.... r & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV defeate. • 13-136 - 06- MARCH -2011 Tom / Jim, The low pressure pilot (LPP) on 1J -136 (2 1 • 54 and 206 -155) was defeated • - 13/06/2011 when the B -sand isolation plug was released and returned to service after • •• • shut in since Augu • , 2010. As of 22:00 hrs on 03/06/2011, wellhead injection pressure is 50 psi; injection rate is • • I bwpd. T - • P 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 pre : • re has increase. • above 500 psi or the B -sand has been isolated again and the LPP /SSV function is returned • ormal, in accordance with _ • inistrative Approval No. CO 406B.001." Please let me know if you have a • • uestions. David Lagerlef /Dan : - : den CPF1 Productio• gineers n1269 @c• • • ophillips.com 659- pa •er 659-7000 765 7/5/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 29, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile / Water Flow Log: 1J -136 Run Date: 4/20/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -136 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-23331-00 Water Flow Log _ 1 Color Log 50- 029 - 23331 -00 ? r M 2 ZO Injection Profile Log 1 Color Log 50- 029 - 23331 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273- 3527� _ �j Fax: 907- 273 -3535 klinton.wo ib 1Rc 0 6 1011 ate: Signed: CA • . From: CPF1 Prod Engr Sent: Sunday, March 06, 2011 10:13 PM To: 'jim.regg @alaska.gov'; 'Maunder, Thomas E (DOA) ' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gauer, Jenn L; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV defeated on 13-136 - 06- MARCH -2011 Tom / Jim, The low pressure pilot (LPP) on 1J -136 (206 -154 and 206 -155) was defeated on 03/06/2011 when the B -sand isolation plug was released and returned to service after being shut in since August 01, 2010. As of 22:00 hrs on 03/06/2011, wellhead injection pressure is 50 psi; injection rate is 960 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi or the B- sand has been isolated again and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 pager 659 -7000 765 B AR e tali Page 1 of 1 Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Saturday, July 17, 2010 7:16 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; Pierson, Chris R Subject: LPP/SSV Returned to Service on 1J-136 - 07-16-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 1J-136 (206-154 and 206-755a was returned to service on 07!16/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 634 psig; injection rate is 667 bwpd. This pilot had been defeated on 07/15/10 in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Office: 265-6112 (659-7493 this week) ~~ v~ ~~i. r 7 (~ ~ Cell: 240-5056 7/19/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Thursday, July 15, 2010 4:47 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; Pierson, Chris R Subject: LPP/SSV defeated on 1 J-136 - 07-15-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 1J-1361206-154 and 206-155- was defeated on 07/15/2010 when the well was returned to injection service after being shut in since 05/09/10. Current wellhead pressure (as of 16:41 07/15/10) is 493 psi; injection rate is 706 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is retumed to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Office: 265-6112 (659-7493 this week) Cell: 240-5056 7!16/2010 • i ~, ~ b;~ :fin r ~ 2~ ~. .~ ~n ° ~; ."~ ~: ~~ z ~~ ~~~~ ~; .- _, ~ ~~ ,,,~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc MEMORANDUM TO: Jim Regg n I P.I. Supervisor ~' 1 I l~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-136 KUPARUK RIV U WSAK 1J-136 Src: Inspector NON-CONFIDENTIAL Reviewed By:_ P.I. Suprv J~~ Comm Well Name: KUPARUK RIV U WSAK 1J-136 API Well Number: 50-029-23331-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100516141342 Permit Number: 206-154-0 Inspection Date: 5/14/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 0 -i 1J-136 ~ 3503 ~ ' 276 ~ 170 Well Type Inj. ~ N T T ~ IA P.T.DI 2061540 TypeTest SPT TCSt pSl I 1700 ~ OA 173 183 ~_ ' 670 1660 .~ ] 182 180- InterVal4YRTST p~F P ~ Tubing 600 600 ~ 600 600 Notes: N1i,'~, req ~ ~~~ ;5~~ ~51 '~~}~i, ~ ~ ... .~ ~ ~ } Monday, May 24, 2010 Page 1 of 1 • 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 1 OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1J 05/14/10 ~.b~~ ~ ~ "~ V Colee /Phillips - AES Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubing 657 656 655 654 Interval 4 P.T.D. 2061100 Type test P Test psi 1500 Casing 990 1,700 1,680 1,680 P/F P Notes: OA 165 205 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 Type test P Test psi 1500 Casing 1,098 1,800 1,780 1,780 P/F P Notes: OA 155 156 156 156 Well 1J-118 Type Inj. W TVD 3,599' Tubing 657 658 658 658 Interval 4 P.T.D. 2061760 Type test P Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OA 175 192 177 175 Well 1J-122 Type Inj. G TVD 3,684' Tubing 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casing 809 1,690 1,640 1,620 P/F P Notes: OA 141 214 174 156 Well 1J-127 Type Inj. W TVD 3,482' Tubing 620 620 622 622 Interval 4 P.T.D. 2060470 Type test P Test psi 1500 Casing 1,020 1,700 1,680 1,680 P/F P Notes: OA 206 273 260 253 Well 1J-136 Type Inj. N TVD 3,503' Tubing 600 600 600 600 Interval 4 P.T.D. 2061540 Type test P Test psi 1500 Casing 276 1,700 1,670 1,660 P/F P Notes: OA 173 183 182 180 Well 1J-154 Type Inj. W TVD 3,437' Tubing 624 624 624 624 Interval 4 P.T.D. 2050350 Type test P Test psi 1500 Casing 1,098 1,850 1,840 1,840 P/F P Notes: OA 527 527 527 527 Well 1J-156 Type Inj. W TVD 3,410' Tubing 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casing 1,147 1,900 1,890 1,890 P/F P Notes: OA 206 206 206 205 Well 1J-160 Type Inj. W TVD 3,212' Tubing 626 626 626 y~ 625 Interval 4 P.T.D. 2070150 Type test P Test psi 1500 Casing 925 1,680 1,650 1,640 P/F P Notes: OA 332 333 333 334 r r -~<. ~ ~ a::y ~ ; ~~ ~ ~, it ~ u MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s V Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 1,866 1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test Y "~ V INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s ~~~~ l+! ~~ TA S TE OF ALASKA ~1AY 1,0 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operetions, ~c{y~' u~. Repair w ell ~ Isolate B Sand _ ~ Plug Perforations ~ Stimulate ; Other g ~ Pull Tubing ~'' Phrforate New Pbol ~ Waiver = M ~ ~~ ~ ~ r I- Time Extension ~' Change Approved FYogram ~ Operat. Shutdow n ~ Pbrforate ~ Re-enter Suspended Well 2.Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Devebpment r Exploratory ~ 206-154 3. Address: Stratgraphic ~ Service +!i API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23331-00 7. Property Desig~tation: ` 8. Well Name and Number: ADL 25662 & 380058 ~ 1J-136 9. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17507 feet Plugs (measured) None y true vertical x3489 feet Junk (measured) None Effective Depth measured 17495 feet Packer (measured) 8990, 9039, 9040 true vertical 3488 feet (true vertucal) 3498, 3505, 3505 Casing Length Size MD TVD Burst Collapse CONDUCTOR 34 78 20 121 121 0 0 SURFACE 3458 18.187 3501 2196 0 0 WINDOW D-SAN 10 12 9100 3512 0 0 D-SAND LEM 217 8.49 9240 3534 0 0 D-SAND -- HH A: 264 8.54 9347 3552 0 0 INTERMEDIATE 9688 9.625 9730 3591 0 0 LINER B-SAND 8298 9.625 17495 3488 0 0 Perforation depth: Measured depth: Slotted liner 9344-12824,13067-17185, 9750-17455, True Vertical Depth: 9344-9700, 9697-9664, 3632-3527 ~~~ _ ~~ v~~~~~ Tubing (size, grade, MD, and TVD) 4.92, L-80, 9039 MD, 3505 TVD Packers & SSSV (type, MD, and TVD) SLEEVE-O -BAKER 4.5"CMD SLEEVE W/ CAMCO 3.812" 'DB' PROFILE @ 8990 MD, 3498 TVD LOCATOR -BAKER 5.16" O.D. I.D. 3.95". GBH-22 SEAL ASSEMBLY @ 9039 MD, 3505 TVD SEAL ASSY -BAKER 4.74" SBE SEAL ASSY. @ 9040 MD and 3505 TVD NIPPLE - 4-1/2" Camco "DB-6" Nipple w/ 3.875" No-Go Profile. @ 505 MD and 505 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 423 190 960 Subsequent to operation 447 192 830 13. Attachments 1 Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service -+,~ Well Status after work: Oil [` Gas ~ WDSPL Daily Report of Well Operations X GSTOR ("' WAG ~'? GASINJ [` WINJ +!i SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A or Sund Number re uired here Contact Bob Christensen/Darrell HumDhrev Printed Name Darrell R. HumDhrev Title Production Engineering Specialist Signature Phone: 659-7535 Date Form 10-404 Revised 7/2009 ~~`~ ~~r 1 ~ ~uw ,S ~2 Submit Original Onl _.~~~ ~~ 1J-136 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/08/10 ISOLATE WSAK B-SAND WITH 3.562" OD PLUG. SET PLUG IN CAMCO DB-6 PROFILE NIPPLE AT 9134' RKB. RAN 1.8 5" OD X 3.6' EQUALIZING PRONG (1-3/8" FISHNECK) AND SET IN PLUG AT 9134' RKB. .- ConocoPhillips AI.{~h,l It 1~ Wsll Confi : Mul[i le Latarab - 1J-1 36 M72070 503.59 PM Schematic - A cNal CONDUCTOR 3,• mamatae. 43-tzt NIPPLE, 503 INJECTION, 2,zt t SURFACE, 0.13,501 SLEEVE-0, e,s90 LOCATOR, 9,039 SEAL ASSY, s.o4o wneew D-sane, s.a.1o-s.lo0 D-SarM LEM, 9,023-9,240 D-s.na -- RR A..y 9,083-9,347 TERMEDIATE, 97-9,730 SLOTS, 9,750-17,455 Liner 8-Sane 9,19]-1],195 •, TD l1 J-1361, 17,507 KUP 1 J-136 Well Attributes Max An le 8 MD TD Wellbore API/U WI Fleltl Name Well StrNa 500292333100 WEST SAK INJ Inc! (°) MD (RKa) Act Btm (/D(B) 17,507.0 Comment H7S (ppm) SSSV: NIPPLE Datr Annotaton Entl Date KB-Ortl (tt) Last WO: 44.00 Rlg Release Datr 1/3/2007 Annotation Last Tag: DepN (flKB) End Datr Annotaton Rev Reason: Set Plug/Prong, Isolate B-Sand Last Mod ... Imosbor End Dale 4/17Y2010 Casin Strin s Casing Deaerlpeon CONDUCTOR 34" Insulated String 0... 20 String ID ... 19.250 Top (RKBj 42.9 Set Depth (f... S 121.0 et Depth (TVD) ... 121.0 String Wt.. 94.00 String ... K-55 String Top Thrd WELDED Casing Deacrlptlon SURFACE String 0... 133/8 Slring ID ... 12.415 Top (Po(B) 42.9 Set Depth (f... S 3,501.0 at Depth (TVO) ... 2,236.4 String Wt... 68.00 String ... L-80 S[ring Top ThM Buttress Thread Caaing Deacrlptlon Window 0.Sarld String 0... 12 String ID ... 10.000 Top (Po(B) 9,090.0 Set Depth (f... S 9,100.0 et Depth (TVD) ... 3,553.0 String Wt... 40.00 String ... L-80 Slring Top Thrd Caaing Description INTERMEDIATE String 0... 95/8 String ID ... 8.835 Top (ftKB) 41.4 Set Depth (f... S 9,729.7 et Depth (TVD) ... 3,631.2 S[ring Wt... 40.00 String ... L-80 String Top Thrd BTC-M Casing Deecriptlon DSand -- HH Assy String D... 5 1/2 String ID ... 4.950 Top (RKB) 9,082.9 set Depth (f... S 9,346.8 at Depth (TVD) ... 3,592.7 Slring Wt... 15.50 String ... L-80 Slring Top Thrtl BTC-M Caaing Deecriptlon Liner B-Sand String 0... 51/2 String ID ... 4.750 Top (ftKB) 9,196.8 Set Depth (f... S 17,495.0 et Depth (TVD) ... 3,528.4 Slring Wt... 15.50 String ... L80 String Top Thrtl BTCM Liner Details Top (RKB) Top Depth (TVD) (RKB) Top Inc! (°) I trm Descrlpto n Comment Noml... ID (In) 9,196.8 3,567.1 79.89 P ACKER "HRD" ZXP Liner Top Packer9-5/8" (7.50" X 8.43") 7.650 9,215.4 3,570.4 79.97 N IPPLE "RS" Packofr Seal Nipple 7.00" (6.19" ID x 7.65" O 7.650 9,219.4 3,571.1 79.99 H ANGER FlexLOdt Liner Hanger 7"x 9-5/8" (6.23" X 8.34") 6.230 9,227.2 3,572.5 80.02 X O BUSHING XO Bushing 4.90" ID, 7.6T' 00 4.900 9,228.9 3,572.8 80.03 S BE 190-47 Casirg Seal Bore Ext. 4.75'ID x 6.31"OD 4.750 10,238.7 3,636.9 95.90 X O5.5x4.5 4.750 Casing Deacripbon String 0... String ID ... Top (RKB) Sat DepN (f... Set Depth (TVD) ... Slring Wt... String ... String Top ThM 0.Sand LEM 5.21 3.980 9,023.1 9,240.0 3,574.7 12.60 L-80 IBT-mod Tubin Strin s Tubing Deacrlptlon String 0... String ID .. Top (RNB) Sat Depth (f... Sat Depth (TVD) ... String Wt... String ... Slring Top Thrd TUBING 5.2 3.958 37.8 9,057.5 3,547.4 12.60 L-80 IBT-mod Com letion Det ails Top (fIXB) Top Depth (TVD) (RKB) Top Inc! (°) I trm Deacrlpto n Comment Noml... ID (Inj 37.8 37.8 -0.Ot H ANGER Vetco Gray 11"x 4-1/2" w/ 4.909" MCA Top Connection (Pup 4.36') 3.958 505.5 505.5 6.75 N IPPLE 4-1/2" Cameo "DB-6" Nipple w/ 3.875" Na-Go Profile. 3.875 8,989.7 3,541.0 84.32 S LEEVE-0 Baker 4.5"CMD Siidirg Sleeve wl Cameo 3.812"'DB' Profile(OPEN) 3.812 9,039.4 3,545.4 83.34 L OCATOR Baker Locator 5.16" O.D. I.D. 3.95". GBH-22 Logdng seal assembly 3.958 9,040.5 3,545.5 83.32 S EAL ASSY Baker 4.74" SBE Seal Assy. 3.880 Perforations 8 Slots Top (RKB) Btrn (RKB) Top (TVD) (RKB) elm (TVD) (RKB) Zona Dale Shot Dens (sh... Type Comment 9,750 17,455 3,632.3 3,526.7 W 8 1 S B, WS C, WS , WS C, WS,B, J-136 12110/2006 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 dreumferential adjacent rows, 3" centers staggered 18 deg, 3' rwn-slotted ends Notes: General 8 Safe End Gate Annotation 1/1!2007 NOTE: MULT-LATERAL WELL, 1J-136 (B!CSANDS), 1J-136L1 (DSANDS) 4/1 712 01 0 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Stn Top (RKB) Top Depth (TVD) (RKB) ToD Inc! (°) Make Model OD (in) Sarv Valve Typs Latch Type Port Size (ln) TRO Run (pai) Run Datr Com... 1 2,211.4 1,906.0 67.11 CAMCO KBMG 1 INJ GLV BK-5 0.188 1,450.0 1/28/2007 • Maunder, Thomas E (DOA) Page 1 of 1 From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Wednesday, April 14, 2010 8:36 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R Subject: LPP/SSV Returned to Service on 1J-136 - 04-14-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 1J-136 (206-154 and 206-155) was returned to service on 04/14/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 603 psig; injection rate is 930 bwpd. This pilot had been defeated on 03/27/10 in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 Daniel Bearden CPF1 Production Engineer Conocophillips Alaska, Inc. 659-7493 -- L.'.'ed ~,L~~aw%r'r ~;1 ~r ..4 ~'.F z~. ~J f"v" 4/14/2010 • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Friday, April 09, 2010 9:48 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 Subject: LPP/SSV defeated on 1J-136 - 4-09-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 1J-136 (206-154 and 206-155) was defeated on 3/27/2010 when the well was returned to injection service after being shut in for 31 days. Downhole surveillance occurred 3/27/10 - 3/28/10 and the well was shut-in 3/29/10 pending the next step in the wellwork plan for this well. The remaining wellwork was completed for well on 4/8/10. Current wellhead pressure (as of 09:45 4/09/10) is 252 psig; injection rate is 424 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 4066.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 Daniel Bearden CPF1 Production Engineer ConocoPhillips Alaska, Inc. 659-7493 4/9/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@~nocophillips.com] Sent: Wednesday, March 31, 2010 7:22 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 Subject: RE: LPP/SSV Returned to Service on 1J-136 - 3-29-2010 Tom 1 Jim, The low pressure pilot {LPP) on dual lateral injector 1J-136 (206-154 and 2fl6-155) was returned to service on 3/29/2010 after the well was shut in at ~e completion of surveillance logging. The LPP had been de#eated on 3/27/2010 and the well never reached 500 psi WHIP before it was Sl. 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 Rage: 659-7000 pager # 765 .. ~':wr 1'a"i~~4wa~.J~ .~: C' K~ 3 s tg ~~FF 4,'+ 3/31 /20i 0 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.comJ Sent: Saturday, March 27, 2010 7:25 PM To: CPF1 Prod Engr, Maunder, Thomas E (DOA); Regg, James 8 (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R Subject: RE: LPP/SSV defeated on 1 J-136 - 3-27-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 9J-136 (206-154 and 206-155) was defeated on 3/27/2010 when the well was returned to injection service after being shut in for 31 days. Current wellhead pressure (as of 1900 3/27) is 160 psig; injection rate is 960 bwpd. We are planning on doing some downhole surveillance before shutting the well back in, weather permitting it should be less than one week. This surveillance will allow us to determine the next step in the weliwork plan for this well. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Kenneth Lloyd Kenneth Lloyd Martin/David Lloyd Lagerlef Prod. Eng. Regional Advisor/Staff Engineer ;;~^;,, ~~ t °'~~t - ~~ ~ ~ ' ~= ~ ~ ~ ~`' CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 Voice Page: 659-7000 pager # 765 3/31/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Tuesday, February 23, 2010 6:58 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; Pierson, Chris R; Hutcherson, Mark R Subject: LPP/SSV returned to service on 1J-136 - 23-Feb-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 1J-136 (206-154 and 206-155) was returned to service on 2/ 23 /2010 when the wellhead injection pressure rose a ove t e setting of the low pressure pilot. Current wellhead pressure is 540 psig; injection rate is 1150 bwpd. This pilot had been defeated on 2/14/10 in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kenneth Lloyd Kenneth Lloyd Martin/David Lloyd Lagerlef Prod. Eng. Regional Advisor/Staff Engineer CPF1 Production Engineers Kuparuk River Unit Phone: (907) 659-7493 dy~s~~ ~~~ ~.~~ Voice Page: 659-7000 pager # 765 2/23/2010 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Monday, February 15, 2010 8:50 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; Pierson, Chris R Subject: LPP/SSV defeated on 1J-136 - 14-Feb-2010 Tom /Jim, The low pressure pilot (LPP) on dual lateral injector 1J-136 (206-154 and 206-155) was defeated on 2/14/2010 when the well was returned to injection service after being shut in for 32 days. Current wellhead pressure (as of 0830 2/15) is 465 prig; injection rate is 950 bwpd. We expect to have the LPPs returned to service in approximately 1-2 days. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 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 ~, ~ Zoe CPF1 Production Engineers ~~`'~~~~ ~~~ -~ Kuparuk River Unit Phone: (907) 659-7493 Voice Page: 659-7000 pager # 765 2/16/2010 ! ~3 (~~ 0~~~ Y`d~s ( /'a (~~ Ib~s3 Se6[iunberger Schlumberge~ -DCS 2525 Gambell Streel, Suite 400 Anchorage,AK 99503-2838 ATTN: Belh Well NO. 5359 L ~ ~, ~ ~ Company: ~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ~~ ~ ~ ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 J 1~ Field: Kuparuk ~ob ~ Log Description Date BL Color CD ~~'~~5 1J-136 tE-166 ~~-»ZA 1Y-O6A B2WV-00017 82Wy.00024 B2WY-00025 AXBD-00042 M3~-00056 MEM INJECTION PflOFILE - MEMINJECTIONPROFILE ~ MEMPpODUCTIONPpOFQE MEM PRODUCTION PpOFILE - SFRT - 0723/09 0824/09 p~5pg OB/2g/09 09IOSM9 1 1 ~ 1 1 ~ ~ ~ 7 ~ riease sign ana raturn o~e copy of this trensmittal to Beth at the above adtlress or fax to (907) 561-8317. Thank you. 09l11/09 : ,,; , _ 4r ~- ~ ~M'~ ~ , `;'d ~~ ~r % ~. , t ~! ``;K~i, ~. ~ : ~ ~ ._ -~.. o. „ ~..w.. ,,,.v. - `1~ - ~ MEMORANDUM To: JimRegg '~ `5~~1 P.I. Supervisor ~~ l `s ~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-136 KUPARUK RIV U WSAK IJ-136 Src: Inspector NON-CONFIDENTIAL Reviewed ByT: P.I. Suprv Comm Well Name: KUPARUK RN U WSAK 1J-136 Insp Num: mitRCN090526114038 Rel Insp Num: API Well Number: 50-029-23331-00-00 Permit Number: 206-154-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. Well IJ-136 Type Inj. W TVD 3503 IA 1420 1960 1940 7940 P.T.D 2061540 TypeTest SPT Test psi 1960 QA 193 195 195 196 Interval 4YRTST per, P Tubing , 628 628 628 627 Notes: Wednesday, May 27, 2009 Page I of 1 LPP/SSV returned to service on 1J-136 (PTD 206-154, 206-155) Page 1 of 1 • • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Tuesday, April 07, 2009 2:54 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Alten; Pierson, Chris R; Hibfer, Kaycee; Gangl, Melissa A; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on 1 J-136 (PTD 206-154, 206-155) Tom /Jim, The LPP/SSV function was returned to normal on West Sak injector 1J-136 (PTD 206-154, 206-155) on 3/31/2009. The well is currently injecting 978 bwpd at 556 psi wellhead pressure. Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhitlips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com i A ? '±(~ ~~ From: NSK West Sak Prod Engr Sen#: Friday, Mdreh 20, 2009 5:37 PM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPFl DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; Pierson, Chris R; NSK West Sak Prod Engr; Hibler, Kaycee; Gangl, Melissa A Subject: LPP/SSV defeated on i]-136 Tom /Jim, The low pressure pilot (LPP) on 1J-136 (PTD 206-154, 206-155) was defeated 3/20/2009 when the well was returned to service after being shut in for 34 days. The well is currently taking 1244 bwpd at 429 psi wellhead pressure. 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. 5/26/2009 LPP/SSV defeated on 1J-136 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Friday, March 20, 2009 5:37 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; Pierson, Chris R; NSK West Sak Prod Engr; Hibler, Kaycee; Gangl, Melissa A Subject: LPP/SSV defeated on 1J-136 Tom /Jim, The low pressure pilot (LPP) on 1J-136 (PTD 206-154, 206-155) was defeated 3/20/2009 when the well was returned to service after being shut in for 34 days. The well is currently taking 1244 bwpd at 429 psi wellhead pressure. 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. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 3/23/2009 ~~,1~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061540 Well Name/No. KUPARUK RIV U WSAK 1J-136 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23331-00-00 MD 17507 TVD 3489 REQUIRED INFORMATION Completion Date 1/3/2007 Completion Status 1-OIL Current Status 1WINJ Mud Log No DATA INFORMATION Types Electric or Other Log s Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~I dg --- _ __ Cement Evaluation bt,~`1,,,~„~ Cement Evaluation (~i0 D Asc Directional Survey / "E D D Asc Directional Surrey N L•ED C Lis 14511 Induction/Resistivity ~pt 14511 LIS Verification ~ VRpt 14511 LIS Verification yLge,~ Injection Profile Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y,© Chips Received? -~-~-P~- Analysis ~i- Received? Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No 5 Col 1 5 Coi 1 5 Blu Interval Start Stop OH / CH Received Comments 4680 9765 Case 12/21/2006 CBL, USIT, GR, Welltec Tractor 10-Dec-2006 4680 9765 Case 1/5/2006 CBL, USIT, GR, Welltrac, 10-Dec-2006 REDO 8693 17507 Open 3/27/2007 0 8858 Open 3/27/2007 PB 1 Open 3/21/2007 Multiple LIS Veri w/PB1 ~ 3451 17469 Open 3/21/2007 LIS Veri, GR, ROP, FET 3451 8858 Open 3/21/2007 P61 LIS Veri, GR, ROP, FET 8800 9340 Case 2/13/2008 Injection profile, Spin, Temp, Pres, Gardio 2-Feb- 2008 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~N ~_. Formation Tops ~ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061540 Well Name/No. KUPARUK RIV U WSAK 1J-136 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23331-00-00 MD 17507 ND 3489 Completion Date 1/3/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y J Compliance Reviewed By: Date: • • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~o Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-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 1 J-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 1 J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1 J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-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 1J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 8" NA 8" NA 1.28 9/6/2008 LPP/SSV returned to service or~IJ-136 and 1E-112 Maunder, Thomas E (DOA) from: NSK West Sak Prod Engr [n1638(~conocophillips.com) Page 1 of ~ /1 ~~ Sent: Monday, April 21, 2008 4:19 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Tech; CPF1 Prod Supt; CPF1 DS Lead Techs; NSK West Sak Prod Engr; Pierson, Chris R; Jenkins, Lubbie Allen; Targac, Gary Subject: LPP/SSV retumed to service on 1 J-136 and 1 E-112 Tom/Jim, The LPP/SSV function was returned to normal on 1J-136 (PTD # 206-154, 206-155) on 4/21/08. The well is currently injecting 1525 bwpd at 623 psi wellhead pressure. Also, the LPP/SSV function was retumed to normal on 1E-112 (PTD 204-091, 204-092, 204-093) on 4/21/08. The well is currently injecting 1772 bwpd at 552 psi wellhead pressure. Please let me know if you have any questions. Regards, Hai Hunt From: NSK West Sak Prod Engr Send Saturday, April 12, 2~8 9:29 AM To: NSK West Sak Prod Engr; 'tom.maunder~alaska.gov`; jim_regg~admin.state.ak.us' Cc: NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; AI15up-Drake, Sharon K; CPFi DS Lead Teths; NSK Problem We11 Supv; Pierson, Chris R Sub~ecib LPP/SSV retumed to service on 13-156. LPP/SSV defeated on iJ-136. Tom /Jim, The LPP/SSV function was returned to normal on 1J-156 (PTD # 206-067, 206-068, 206-069) on 4/10/08. The well is currently injecting 1782 bwpd at 554 psi wellhead pressure. The LPP/SSV on 1J-136 (PTD # 206-154, 206-155) was defeated 4/11/08 when the well was returned to production after a ~1 month shut in period (rig workover on an adjacent well). The LPP and SSV have been tagged and are recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 1458 bwpd at 451 psi wellhead pressure. Judging by the current wellhead pressure trend, I expect we will be able to return the LPP/SSV to service in M1 week. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Please let me know if you have any questions. Regards, Hai Hunt 4/21/2008 • Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 02/12/08 ax NO. 4585 4_as8 , ~, `~F.,,,. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD r~ 1J-136 11964574 INJECTION PROFILE U 02/02/08 1 2A-04 11964576 INJECTION PROFILE 02/04/08 1 1A-01 11970631 PRODUCTION PROFILE 02/06/08 1 1Y-17 11994613 GLS 02/09108 1 1A-17 11996600 PRODUCTION PROFILE / 02/10/08 1 2Z-13A 11996601 SBHP SURVEY (o - 02/11/08 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-136, b~~~C in service on 1J-160 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, November 07, 2007 10:52 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: LPP/SSV defeated on 1J-136, back in service on 1J-160 Tom /Jim, Page 1 of 1 The low pressure pilot (LPP) on 1J-160 has come up above 500 psi and the LPP/SSV function was returned to normal on 11/7/2007. Permit to drill numbers: 1J-160 207-015, 1J-160L1 207-016, 1J-160L2 207-017. The low pressure pilot (LPP) on 1J-136 was defeated on 11/4/2007 when the well was re#umed to service after an extended shut in time (the well had been shut in since 6/8/07 due surface proximity to a workover rig). Current wellhead pressure is 461 psi; injection rate is 1277 bwpd. We expect to have the LPPs returned to service within a week. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." Permit to drill numbers: lJ-Y36 2~t6-1;54, 'tJ-136L1 206-155. The AOGGC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 11 /7/2007 MEMORANDUM • TO: Jim Regg ~ P.I. Supervisor ~C~'~~ 7~t 2~u FRONt: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 27, 2007 StiBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-136 KUPARUK RIV U WSAK 1J-136 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv 1~~ Comm Well Name: KUPARUK RIV U WSAK iJ-136 API Well Number: so-029-23331-00-0o Inspector Name: Bob Noble Insp Num: mitRCN070627092206 Permit Number: 206-154-0 Inspection Date: 6/26/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - Well ~ 1J-136 Type Inj. `~' TVD 3 o IA j Isoo zllo 2090 zo9o ~ j P.T.D~ zo6lsa° '~iTypeTest sPr I Test psi ~ zlto pA - Ibo I Ibo ~ Ibo ~ Ibo _ Interval ~IT~- P/F P ~ Tubing'. azs ~azs I azs av j ~ Notes: ~~?~ ~G~ ~~ `J!t`'.Ss~~,,'t_ i ~'Z-~~S~.. Wednesday, June 27, 2007 Page 1 of 1 West Sak LPP Defeat Update ~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Monday, July 09, 2007 4:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK West Sak Prod Engr Subject: West Sak LPP Defeat Update Tom /Jim This email is to notify the AOGCC that 1J-105 and 1J-160 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been defeated in accordance with "Administrative Approval No. CO 4066.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". Both wells required anon-adjustable choke insert on the water injection line to limit and control water injection at lower rates. Following are the current well conditions: 1J-105 Converted from pre-production to injection 07/06/2007, LPP defeated 7/6/2007. Injecting 2200 bwpd at 0 psi. 1J-160 Converted from pre-production to injection 07/01/2007, LPP defeated 7/6/2007. Injecting 1250 bwpd at 80 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. This email is also to notify the AOGCC that 1J-180 and 1J-136 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been placed back in service 1J-180 LPP defeated 06/09/2007, back in service 06/28/2007 1J-13~6--L-P~P defeated 06/08/2007, back in service 07/01/2007 Regards, ~®EO' ,S Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 7/10/2007 - - ~,e~~~ i ~- ~~-o~ ECEiVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN I q ZOO7 REPORT OF SUNDRY WELL OPERATIONS nla~~~ tljl t~ cas Cons. Commission 1. Operations Performed: Abandon ^ Repair WeII ^ Plug Pertorations ^ Stimulate ^ Other ~g ~1e(~g~d to Inj Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-154 / " 3: Address: Stratigraphic ^ Service ~ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23331-00 ` 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1 J-136 8. Property Designation: 10. Field/Pool(s}: ADL 25662 ~ 380058 ~ Kuparuk River Field /West Sak OiI Pool 11. Present Well Condition Summary: Total Depth measured 17507 r feet true vertical 3489' ~ feet Plugs (measured) Effective Depth measured 17495' feet Junk (measured) true vertical 3488' feet Casing Length Size. MD ND Burst Collapse Structural CONDUCTOR 140' 20" 140' 140' SURFACE 3392' 13-3/8" 3501' 2196' WINDOW D-SAN 1' 9-5/8" 9085' 3511' INTERMEDIATE 9620' 9-5/8" 9729' 3591' B/C-SAND LINEF 8299' 5-1/2" 17495' 3488' Perforation depth: Measured depth: Alternating pipe/slotted li ner 9750' - 17455' true vertical depth: 3592' - 3487 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9056' MD. Packers &SSSV (type & measured depth) ZXP Liner Top Packer @ 9023' PKR = 3503' SSSV= NIP SSSV= 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1123 373 44 1042 362 Subsequent to operation 1948 ~ 1608 187 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WIND 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. Exem t: ,/n ~M If~'4 ; , - ,, , 1 contact Bob Christensen /Bob Buchholz Printed Name Robert W. Bu chholz Title Production Engineering Technician Signature d~~c'~ -' ~ ~'~ ~j ~ Phone 659-7535 Date ~ /f~~~ / ~I ~-- G LT 0 7 Form 10-404 Revised 04!2004 ~~ ~~~ ~ ~ ~Du/ 3 Submit Original ORIGINAL 1J-136 ~'~ DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/08/07 Commenced Water Injection. Notification of LPP Defeat on West Sak Pre-Produced Injectors Subject: Notification of LPP Defeat on West Sak Pre-Produced Injectors From: NSK West Sak Prod Engr <n1638@conocoplullips.com> Date: Mon, 11 Jun 2007 15:44:53 -0800 To: Jim Regg <jim regg@admin.state.ak.us>, Tom Maunder <tom_maunder@admin.state.ak.us> CC: NSK West Salo Prod Engr <n1638@conocoplullips.com> Tom /Jim, ~~ ~~ ~_ ~~~ 1---~Y aO6 - \ Sv This email is to notify the AOGCC that 1J-136 and 1J-180 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been defeated in accordance with "Administrative Approval No. CO 4066.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". Both wells required anon-adjustable choke insert on the water injection line to limit and control water injection at lower rates. Following are the current well conditions: 1J-136: Converted from pre-production to injection 06/08/2007. Injecting 1900 bwpd at 92 psi. 1J-180: Converted from pre-production to injection 06/09!2007. Injecting 1050 bwpd at 17 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 'I 1 of 1 6/12/2007 1:34 PM WELL LOG TRA1~1SivIITTAL To: State of Alaska March 07, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: 1J-136, PB1, Ll, L1 PB1 & L1 PB2, AK-MW-4725877 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23331-00, 70, 60, 71 & 72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETITRNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 _ , ~ `~ r , £'~ Date: ~' ~~ `~`~ ~r y; ?, ~'+;~"t1";~~~~84F~~ ~ e _. ;~ j Signed: ' . ` ~---""~._ 1,5~/ i ~~ st ~ ~ ,J f ';~ ~c~ ~!J ~ C®11T~EIt~A7~®1!T C®MIIIISSI®1~T Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-136 Sundry Number: 307-074 Dear Mr. Buchholz: • S.9R,4W PQUAI, I;OVEl3WOR 333 W. 7th 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 (907j 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this !io day of February, 2007 Encl. y-L../ ,~, Sincerely, .- - - D~ ! ~ ~ ,a~-o7 E EIVED ~- T a • I~ C ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION " ~ r 2 7 ~~ EB 2007 APPLICATION FOR SUNDRY APPROVA 20 AAC 25.280 ~laska Qii +~ Gas Cons. Commission 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^/ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Pre-Producer to Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 206-154 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23331-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:. where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q 1J-136 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25662 & 380058 RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17507' 3489' ~ 17495' ~ 3488' Casing Length Size MD TVD Burst Collapse. CONDUCTOR 140' 20" 140' 140' SURFACE 3392' 13-3/8" 3501' 2196' WINDOW D-SAND 1' 9-5/8" 9085' 3511' INTERMEDIATE 9620' 9-5/8" g72g' 3591' B/C-SAND LINER 8299' 5-1/2" 17495' 3488' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Alternating pipe/slotted liner 9750' - 17455' 3592' - 3487' 4-1 /2" L-80 9056' Packers and SSSV Type: Packers and SSSV MD (ft) ZXP Liner Top Packer @ 9023' PKR = 3503' SSSV= NIP SSSV= 504' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: March 25, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title: Production Engineering Technician Signature Phone 659-7535 Date Z`Z~ cj ommission Use Only Conditions of approval: Notif Commission so that a re resentative ma witness Sundry Number: y p y Plug Integrity ^ BOP Test ^ Mechanical Integrity Test '`~ Location Clearance ^ ° Other: ~t~~CT J-~rjQrcCTbc' ~C` M~~ W~~~~~'~~~'G~CE~ S~G.V~`~1?~ Subsequent Form Required: ~®~ ~ ~~"~ ~'IQl APPROVED BY 2~~J D~,~ Approved by: COMMISSIONER THE COMMISSION Date: l/Q Form 10-403 Revised 06/2006 ~ ~ Submit in Duplicate ~, dr%/ate ~ z'Z~-°7 • ! 1 J-136 DESCRIPTION SUMMARY OF PROPOSAL 1 ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Dual-lateral Well 1 J-136. Plans are to pre-produce well for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-136 will provide pressure support for the West Sak B sands. The 13-3/8" Surface casing (3501' and / 2196' tvd) was cemented with 690 sx AS Lite followed by 220 sx DeepCRETE. The 9-5/8" Intermediate casing (9730' and / 3591' tvd) was cemented with 750 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 7" x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 9023' and / 3503' tvd, Upper B sand HRD ZXP 7" x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Ext. located @ 9196' and / 3527' tvd. The top of West Sak D sand was found at 9081' and / 3510' tvd. D sand Lateral window top is located @ 9084' and / 3511' tvd. The top of West Sak B sand was found at 9681' and / 3587' tvd. • KRU 1 J-136 * -- ~ ~ G ~- S ~-- ~ \ ~ MEC:~A3~ICAL INTEGRITY REPORT ~. ~ 6 - ~ S ~- =~liD v:-=~: - ~~!\41C~ CD OPER ~ FZELD L~L~.~ ~~yt7GrJ~L. WS . _.. G .. ~ :. S ~ .. ~ . l ~ ~ ~ _ ~ ~ ;.• ALL N U2-ff E R 1.., - ~ ~ Co - ~ ~ Co ~-- n ~ LL DAT_--_ TD : ~~~t5 ~ .. ~j~~~j Tti`D ; : BTD : ?~ _ •?VD Casing: ~~~~ Shoe: ~11~V t-ID ~~ ~ TV'D; liV: ~~ ?~ ~~ T~~i _.:,e.. Shoe . ?~D T`JT ; ~'CP . '•~ '~D _o1e Sipe ~~t~y and ~~'~C'r'.~?~=C~_, ZNTEGRTTY - P4.RT #? TVD, Set at 5 ` c'~ ~Crl f S®~ ~ . ~ nC d` Perks to ~n.:;;lus ?ress Test• _~ l j nin ~0 min Comments . '~'CHP~IIC~~, ?NTEGRI'r T _ PART ~ 2 ~ ~Q ~ h~~ Cement Volumes : A.mt. Liner ~~ Cs~'1:~QS~ DV Cu.t -.rol to cover oers C~. `~d~2o~S ~~h~s ~e ~~~~ ~~ w~~®vs,~ --~ .COQ ~ - _.-:eoretical TOC ~~`C~7®~S ~~~ '" ~\~~ . ~~~~~~~~ Cement Bond Log (Yes or No)~_; In AOGCC File ~.ctp ~occz~~c `~~ ~ v.~h~\~ Ci c-c`.,,Ce ~ ~uC~4.- \J~o~Cc ctt~rc~ ..~.~,-?~~~> 'K:~ =C3L Evalua ~ on, gone a~ove per~s~S 1~.0~,.~ r~~cyctSO•~borr~'~ c5 s S ~ ~1r~--~- ~A~p©~ ~ ~-~ w`~~~w ~ +~'~ prc Ce~r~~~ Chc~.r~\ rcvZ. E~~s V .~~. ~LQ~ Production I.og: Type CONC.LJSIONS: ?art #l: ~ nr i L : ~3-~ \ S `~~L`c Evaluation • ~ 02-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-136 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,693.47' MD Window /Kickoff Survey 8,700.00' MD (if applicable) Projected Survey: 17,507.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 _~r ~ , ,~ Date ~~ 1~1e~~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) aob-~SY ~ ~ 02-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-136 Pb~ Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 45.50' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 8,858.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date, ~ ~ O~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~~~s-~ Randy Thomas Kuparuk Drilling Team Leader Drilling ~ Wells P. O. Box 100360 Anchorage, AK 99510-0360 ~~~~~~~~ ~ ~ ~ ~~ Phone: 907-265-6830 February 5, 2007 Commissioner State of Alaska ~. G ~ ?~J7 Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 'I~sl°~ ' ' - '~~r~~i'ss$°~' Anchorage, Alaska 99501 ~ ~~°"~~~~''~~` Subject: Well Completion Reports for 1J-136 and 1J-136L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-136 and 1J-136L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION EFL ~ 6 2~~7 WELL COMPLETION OR RECOMPLETION REPOF~1~• ~~~mp~~~~l•I 1a. Well Status: Oil ^/ ~ Gas Plugged ^ Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: '` ~~• Development Q, Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: January 3, 2007 - 12. Permit to Drill Number: 206-154 / - 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: November 19, 2006 ~ 13. API Number: 50-029-23331-00 4a. Location of Well (Governmental Section): Surface: 1564' FSL, 2282' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Date TD Reached: December 8, 2006 14. Well Name and Number: 1J-136 At Top Productive Horizon: 969' FNL, 389' FEL, Sec. 11, T10N, R10E, UM 8. KB Elevation (ft): 37' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1771' FSL, 451' FEL, Sec. 14, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 17495' MD / 3488' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558931 ~ y- 5945378 Zone- 4 10. Total Depth (MD + ND): 17507' MD / 3489' TVD 16. Property Designation: ADL 25662 & 380058 TPI: x- 560893 y- 5937581 Zone- 4 Total Depth: x- 560900 • - 5929762 Zone- 4 11. Depth where SSSV set: landing nipple @ 504' 17. Land Use Permit: ALK 2177 & 4604 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3510' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.58# H-40 37' 113' 37' 113' 42" 375 sx AS 1 13.375" 68# L-80 37' 3501' 37' 2196' 16" 69o sx AS Lite, 22o sx DeepCrete 9-5/8" 40# L-80 37' 9730' 37' 3591' 12.25" 75o sx DeepCRETE 5.5" 15.5# L-80 9196' 17495' 3528' 3488' 8.5" slotted liner 23. Perforations open fo Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 9056' 9197' slotted liner from 9196'-9749', 10240'-10558', 11056'-11371', 11821'-12136', 12635'-12989', 13438'-13752', 14245'-14561', 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 15019'-15347', 15847'-16165', 16414'-17003', 17296'-17413' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) Oil Producer -shares production with 1 J-136L1 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) 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". _p,,„,,,,,„_,-~,. ~ OOhri~•, LT30N ~ ~ 100E NONE ~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ L-7•o7 n 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. if no tests were conducted, state "None". 1 J-136 Top West Sak B 9681' 3587' 1 J-136P61 TD 8858' 3478' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Slotted Liner Detail Sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Name Rand Thoma Title: Greater Kuoaruk Area Drilling Team Leader !. ~.(~ l ~~ ~ ~ -- \ ~_~ 3 ..,,, -R.L3one Date Signature ~ ~ L ~ ., INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Date: 1/23/2007 Timc: 13.31:27 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: WeIC1J-136, Tr ue North Sitc: Kuparuk 1J Pad Ve rtical (TVD)Re ference: 1J-136: 126.8 Well: 1J-136 Secfion(VS)Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136 Su rvey Calculation ilethod: Minimum Curva ture Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1J-136 Slot Name: Well Position: +N/-S -543.14 ft North ing: 59453 77.64 ft Latitude: 70 15 40.916 N I +E/-W 136.78 ft Easting : 558930.95 ft ~ Longitude: 149 31 25.027 W ' Position Uncertainty: 0.00 ft ~ Wellpath: 1J-136 Drilled From: 1J-136PB1 500292333100 Tie-on Depth: 8693.47 ft Current Datum: 1J-136: Height 126.60 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angl e: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft 45.50 ft 0.00 ft 0.00 deg 180.00 Survey Program far Definitive Wellpath Date: 1/23/2007 Validated: No V ersion: 1 Actual From To Survey Toolcode Tool Name ft ft ----- - 120.00 815.00 1J-136P61 gyro (120.00-815.00) C B-GYRO-SS - Camera based gyro single shot 848.68 8693.47 1J-136P61 (848.68-8786.52) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C I I 8700_00 17475.72 1J-136 (8700.00-17475.72) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ MD Inch Azim T1'D Sys 1l'D NIS E/W MapIV MapE Tool ~~, ft deg. deg ft ft ft ft ft ft 45.50 0.00 0.00 45.50 -81.10 0.00 0.00 5945377.64 ~ 558930.95 • TIE LINE 120.00 0.20 47.82 120.00 -6.60 0.09 0.10 5945377.73 558931.05 CB-GYRO-SS 171.00 0.14 285.78 171.00 44.40 0.16 0.10 5945377.80 558931.05 CB-GYRO-SS 265.00 0.27 139.61 265.00 138.40 0.03 0.14 5945377.67 558931.09 CB-GYRO-SS 352.00 2.78 197.00 351.96 225.36 -2.15 -0.35 5945375.49 558930.62 CB-GYRO-SS 450.00 6.34 203.00 449.64 323.04 -9.40 -3.16 5945368.21 558927.87 CB-GYRO-SS i 536.00 7.46 210.17 535.02 408.42 -18.60 -7.82 5945358.98 558923.28 CB-GYRO-SS 635.00 9.75 215.20 632.90 506.30 -31.01 -15.88 5945346.51 558915.31 CB-GYRO-SS 735.00 12.62 218.15 730.99 604.39 -46.52 -27.51 5945330.91 558903.80 CB-GYRO-SS 815.00 14.54 214.61 808.75 682.15 -61.66 -38.62 5945315.68 558892.82 CB-GYRO-SS 848.68 14.47 210.72 841.36 714.76 -68.76 -43.17 5945308.55 558888.32 MWD+IFR-AK-CAZ-SC 942.92 13.87 206.23 932.73 806.13 -89.01 -54.18 5945288.21 558877.48 MWD+IFR-AK-CAZ-SC 1037.30 17.05 197.44 1023.70 897.10 -112.37 -63.33 5945264.79 558868.51 MWD+IFR-AK-CAZ-SC 1134.76 21.29 193.44 1115.73 989.13 -143.23 -71.73 5945233.87 558860.35 MWD+IFR-AK-CAZ-SC 1228.85 25.03 191.05 1202.23 1075.63 -179.39 -79.51 5945197.65 558852.85 MWD+IFR-AK-CAZ-SC i 1324.31 29.33 189.97 1287.13 1160.53 -222.26 -87.44 5945154.73 558845.26 MWD+IFR-AK-CAZ-SC 1419.52 33.46 185.70 1368.39 1241.79 -271.37 -94.08 5945105.57 558839.00 MWD+IFR-AK-CAZ-SC 1515.12 36.71 182.56 1446.62 1320.02 -326.16 -97.98 5945050.76 558835.54 MWD+IFR-AK-CAZ-SC 1609.68 42.44 181.81 1519.47 1392.87 -386.33 -100.25 5944990.57 558833.73 MWD+IFR-AK-CAZ-SC 1704.86 45.67 181.69 1587.87 1461.27 -452.47 -102.27 5944924.42 558832.23 MWD+IFR-AK-CAZ-SC 1798.73 49.25 182.85 1651.32 1524.72 -521.57 -105.03 5944855.31 558830.02 MWD+IFR-AK-CAZ-SC 1895.85 53.54 180.56 1711.91 1585.31 -597.41 -107.24 5944779.47 558828.40 MWD+IFR-AK-CAZ-SC 1990.76 56.49 178.87 1766.33 1639.73 -675.15 -106.83 5944701.74 558829.41 MWD+IFR-AK-CAZ-SC 2085.78 62.49 175.78 1814.55 1687.95 -756.87 -102.95 5944620.06 558833.94 MWD+IFR-AK-CAZ-SC i 2180.15 65.96 175.41 1855.58 1728.98 -841.59 -96.42 5944535.40 558841.13 MWD+IFR-AK-CAZ-SC 2275.63 70.43 172.88 1891.05 1764.45 -929.74 -87.35 5944447.33 558850.89 MWD+IFR-AK-CAZ-SC 2370.17 75.31 170.62 1918.89 1792.29 -1019.11 -74.36 5944358.07 558864.57 MWD+IFR-AK-CAZ-SC 2466.49 77.31 168.78 1941.68 1815.08 -1111.18 -57.63 5944266.15 558882.03 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Da[e: 1/23/2007 Time: 13:31:27 PaQc: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1J-136, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-136: 126.6 Well: 1J-136 Section (VS)Reference: Well (O.OON,O.OOE,180.OOF>zi) Wellpath: 1J-136 Survey Calculation 111ethod: Minimum Curvature Db: Oracle Survcv MD Incl A7im TVD Sys TVD N/S E/1ti' MapN A1apE Tool ft deg deg ft ft ft ft ft ft 2562 .02 77.65 165. 14 1962. 40 1835. 80 -1202. 01 -36. 59 5944175 .49 558903 .77 MWD+IFR-AK-CAZ-SC 2656 .89 78.08 161. 08 1982. 35 1855. 75 -1290. 74 -9. 64 5944086 .99 558931 .41 MWD+IFR-AK-CAZ-SC 2751 .03 77.04 158. 83 2002. 63 1876. 03 -1377. 10 21. 86 5944000 .89 558963 .58 MWD+IFR-AK-CAZ-SC 2847 .52 74.33 155. 61 2026. 49 1899. 89 -1463 .28 58. 04 5943914 .99 559000 .43 MWD+IFR-AK-CAZ-SC 2942 .22 75.53 155. 39 2051. 11 1924. 51 -1546 .49 95. 96 5943832 .09 559039 .00 MWD+IFR-AK-CAZ-SC i 3037 .83 74.33 155. 49 2075. 97 1949. 37 -1630 .46 134. 33 5943748 .44 559078 .02 MWD+IFR-AK-CAZ-SC 3133 .17 74.30 156. 45 2101. 75 1975. 15 -1714 .29 171. 71 5943664 .91 559116 .05 MWD+IFR-AK-CAZ-SC 3227 .45 71.25 155. 98 2129. 66 2003. 06 -1796 .69 208. 02 5943582 .81 559153 .00 MWD+IFR-AK-CAZ-SC ~ 3322 .39 77.47 155. 05 2155. 25 2028. 65 -1879 .84 245. 90 5943499 .96 559191 .53 MWD+IFR-AK-CAZ-SC 3416 .75 76.91 154. 82 2176. 17 2049. 57 -1963 .19 284. 88 5943416 ,93 559231 .16 MWD+IFR-AK-CAZ-SC 3466 .52 76.15 154. 70 2187. 76 2061. 16 -2006 .97 305. 52 5943373 .31 559252 .14 MWD+IFR-AK-CAZ-SC 3552 .93 74.51 155. 23 2209. 64 2083. 04 -2082 .71 340. 89 5943297 .87 559288 .10 MWD+IFR-AK-CAZ-SC 3647 .71 75.21 157. 64 2234. 40 2107. 80 -2166 .56 377. 46 5943214 .31 559325 .32 MWD+IFR-AK-CAZ-SC 3742 .63 75.74 157. 42 2258. 21 2131. 61 -2251 .47 412. 58 5943129 .68 559361 .10 MWD+IFR-AK-CAZ-SC 3838 .51 75.42 159. 32 2282. 09 2155. 49 -2337 .79 446. 81 5943043 .65 559396 .00 MWD+IFR-AK-CAZ-SC 3933 .33 75.40 160. 21 2305. 97 2179. 37 -2423 .88 478. 55 5942957 .81 559428 .41 MWD+IFR-AK-CAZ-SC 4027 .56 77.96 161. 69 2327. 68 2201. 08 -2510 .55 508. 47 5942871 .39 559459 .00 MWD+IFR-AK-CAZ-SC 4123 .78 77.54 162. 94 2348. 10 2221. 50 -2600 .13 537. 03 5942782 .04 559488 .26 MWD+IFR-AK-CAZ-SC 4218 .48 76.69 163. 15 2369. 21 2242. 61 -2688 .43 563. 95 5942693 .96 559515 .87 MWD+IFR-AK-CAZ-SC 4314 .18 75.58 163. 58 2392. 15 2265. 55 -2777 .46 590. 55 5942605 .16 559543 .16 MWD+IFR-AK-CAZ-SC 4408 .86 75.71 163. 49 .2415. 62 2289. 02 -2865 .42 616. 55 5942517 .41 559569 .84 MWD+IFR-AK-CAZ-SC 4503 .15 76.55 164. 02 2438. 22 2311. 62 -2953 .30 642. 16 5942429 .74 559596 .14 MWD+IFR-AK-CAZ-SC 4600 .43 76.13 164. 36 2461. 20 2334. 60 -3044 .25 667. 91 5942339 .00 559622 .60 MWD+IFR-AK-CAZ-SC 4694 .51 75.86 164. 53 2483. 97 2357. 37 -3132 .19 692. 39 5942251 .26 559647 .76 MWD+IFR-AK-CAZ-SC 4789 .98 74.97 165. 83 2508. 01 2381. 41 -3221 .51 716. 02 5942162 .14 559672 .09 MWD+IFR-AK-CAZ-SC 4885 .79 76.74 165. 10 2531 .42 2404. 82 -3311 .44 739. 34 5942072 .41 559696 .11 MWD+IFR-AK-CAZ-SC 4981 .19 75.05 165. 10 2554 .67 2428. 07 -3400 .85 763. 13 5941983 .20 559720 .60 MWD+IFR-AK-CAZ-SC 5075 .80 75.79 165. 70 2578 .49 2451. 89 -3489 .45 786. 21 5941894 .78 559744 .37 MWD+IFR-AK-CAZ-SC 5171 .78 76.40 165. 52 2601. 55 2474. 95 -3579 .70 809. 37 5941804 .73 559768 .22 MWD+IFR-AK-CAZ-SC 5265 .59 74.53 166. 26 2625. 09 2498. 49 -3667 .76 831. 50 5941716 .85 559791 .05 MWD+IFR-AK-CAZ-SC 5361 .20 74.24 165. 03 2650. 83 2524. 23 -3756 .96 854. 33 5941627 .84 559814 .57 MWD+IFR-AK-CAZ-SC 5457 .33 74.26 164. 10 2676. 92 2550. 32 -3846 .15 878. 96 5941538 .86 559839 .89 MWD+IFR-AK-CAZ-SC 5552 .50 77.11 162. 26 2700. 45 2573. 85 -3934 .40 905. 65 5941450 .82 559867 .27 MWD+IFR-AK-CAZ-SC 5647 .52 76.07 162. 59 2722. 49 2595. 89 -4022 .51 933. 55 5941362 .94 559895 .86 MWD+IFR-AK-CAZ-SC 5742 .83 75.16 164. 48 2746 .17 2619. 57 -4111 .04 959. 72 5941274 .63 559922 .72 MWD+IFR-AK-CAZ-SC 5836 .32 76.20 162. 83 2769 .30 2642. 70 -4197 .96 985. 22 5941187 .92 559948 .89 MWD+IFR-AK-CAZ-SC 5932 .78 76.49 163. 50 2792 .07 2665. 47 -4287 .68 1012. 36 5941098 .43 559976 .74 MWD+IFR-AK-CAZ-SC 6028 .11 78.25 163. 26 2812 .91 2686. 31 -4376 .81 1038. 97 5941009 .51 560004 .04 MWD+IFR-AK-CAZ-SC 6123 .03 78.56 164. 09 2831 .99 2705. 39 -4466 .04 1065. 11 5940920 .50 560030 .87 MWD+IFR-AK-CAZ-SC ~ 6218 .26 77.83 164. 18 2851 .47 2724. 87 -4555 .71 1090. 59 5940831 .04 560057 .05 MWD+IFR-AK-CAZ-SC 6312 .97 78.26 164. 81 2871 .09 2744. 49 -4644 .99 1115. 36 5940741 .96 560082 .51 MWD+IFR-AK-CAZ-SC 6407 .99 78.39 165. 64 2890 .32 2763. 72 -4734 .97 1139 .09 5940652 .18 560106 .94 MWD+IFR-AK-CAZ-SC 6502 .97 78.14 164 .05 2909 .64 2783. 04 -4824 .73 1163 .40 5940562 .63 560131 .95 MWD+IFR-AK-CAZ-SC 6598 .32 76.41 164. 52 2930 .64 2804. 04 -4914 .25 1188 .59 5940473 .31 560157 .84 MWD+IFR-AK-CAZ-SC 6693 .68 76.48 163. 31 2952 .99 2826. 39 -5003 .33 1214. 27 5940384 .45 560184 .22 MWD+IFR-AK-CAZ-SC 6788 .75 77.51 162. 41 2974 .39 2847. 79 -5091 .84 1241. 57 5940296 .16 560212 .21 MWD+IFR-AK-CAZ-SC 6885 .02 77.09 162. 36 2995 .55 2868. 95 -5181 .35 1269. 99 5940206 .88 560241 .33 MWD+IFR-AK-CAZ-SC 6980 .08 75.74 161. 32 3017 .88 2891. 28 -5269 .15 1298. 79 5940119 .32 560270 .81 MWD+IFR-AK-CAZ-SC 7073 .70 76.06 161. 10 3040 .69 2914. 09 -5355 .11 1328. 04 5940033 .60 560300 .72 MWD+IFR-AK-CAZ-SC 7169 .70 75.37 159. 78 3064 .37 2937. 77 -5442 .77 1359. 18 5939946 .20 560332 .55 MWD+IFR-AK-CAZ-SC 7264 .91 75.32 160. 47 3088 .46 2961. 86 -5529 .39 1390 .49 5939859 .83 560364 .54 MWD+IFR-AK-CAZ-SC 7360 .01 75.91 160 .13 3112 .09 2985. 49 -5616 .12 1421 .55 5939773 .35 560396 .26 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Date: 1/23/2007 Time: 13:3t27 Nage: 3 Field: Kuparuk River Unit Co-ordinate(NF) Reference: Well: 1 J-136, True North Sitc: Kuparuk 1J Pad Vertical (TVD) [icfcrcncc: 1J-136: 126.6 Nell: 1J-136 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) WeI-path: 1J-136 5ur~~ey Calculation Method: Minimum Curvature Db: Oracle __ __ _ __ Surrey - - _ ___ MD Incl Azim TVD Sys TVD N/S E/~V MapN ~IapE Tool ft deg deg ft ft ft ft ft ft i 7455.22 75.95 159.52 3135.24 3008.64 -5702.81 1453.40 5939686.93 560428.79 MWD+IFR-AK-CAZ-SC ~~ 7548.91 75.50 160.57 3158.34 3031.74 -5788.15 1484.39 5939601.84 560460.44 MWD+IFR-AK-CAZ-SC ! 7645.28 75.37 160.94 3182.57 3055.97 -5876.21 1515.13 5939514.03 560491.87 MWD+IFR-AK-CAZ-SC 7738.81 74.66 160.16 3206.76 3080.16 -5961.40 1545.21 5939429.08 560522.62 MWD+IFR-AK-CAZ-SC 7835.65 73.99 161.81 3232.92 3106.32 -6049.55 1575.59 5939341.19 560553.68 MWD+IFR-AK-CAZ-SC ~ i 7930.56 74.02 161.73 3259.08 3132.48 -6136.21 1604.13 5939254.76 560582.90 MWD+IFR-AK-CAZ-SC 8025.73 77.06 160.74 3282.84 3156.24 -6223.45 1633.78 5939167.76 560613.22 MWD+IFR-AK-CAZ-SC 8119.36 76.89 161.17 3303.94 3177.34 -6309.68 1663.55 5939081.78 560643.66 MWD+IFR-AK-CAZ-SC ~ 8216.42 75.28 162.91 3327.28 3200.68 -6399.29 1692.60 5938992.41 560673.41 MWD+IFR-AK-CAZ-SC 8312.10 76.06 162.35 3350.96 3224.36 -6487.76 1720.28 5938904.16 560701.78 MWD+IFR-AK-CAZ-SC 8407.06 74.58 162.16 3375.03 3248.43 -6575.25 1748.27 5938816.90 560730.45 MWD+IFR-AK-CAZ-SC 8502.36 76.41 162.53 3398.90 3272.30 -6663.16 1776.25 5938729.22 560759.12 MWD+IFR-AK-CAZ-SC 8598.36 75.80 162.40 3421.95 3295.35 -6752.02 1804.33 5938640.59 560787.89 MWD+IFR-AK-CAZ-SC 8693.47 76.14 165.01 3445.01 3318.41 -6840.58 1830.21 5938552.25 560814.46 MWD+IFR-AK-CAZ-SC ~ 8700.00 76.25 165.25 3446.57 3319.97 -6846.71 1831.84 5938546.13 560816.14 MWD+IFR-AK-CAZ-SC i ~ 8787.00 77.74 169.13 3466.15 3339.55 -6929.35 1850.62 5938463.65 560835.56 MWD+IFR-AK-CAZ-SC 8882.71 82.01 171.81 3482.98 3356.38 -7022.24 1866.20 5938370.89 560851.87 MWD+IFR-AK-CAZ-SC 8976.03 81.74 174.42 3496.17 3369.57 -7113.95 1877.28 5938279.28 560863.66 MWD+IFR-AK-CAZ-SC 9072.21 82.69 176.94 3509.20 3382.60 -7208.97 1884.45 5938184.33 560871.58 MWD+IFR-AK-CAZ-SC 9167.18 80.81 178.37 3522.83 3396.23 -7302.87 1888.30 5938090.47 560876.16 MWD+IFR-AK-CAZ-SC 9261.51 80.17 179.60 3538.41 3411.81 -7395.88 1889.95 5937997.48 560878.54 MWD+IFR-AK-CAZ-SC 9357.50 80.59 178.53 3554.45 3427.85 -7490.51 1891.49 5937902.88 560880.82 MWD+IFR-AK-CAZ-SC 9451.48 83.38 178.25 3567.56 3440.96 -7583.53 1894.11 5937809.90 560884.16 MWD+IFR-AK-CAZ-SC 9546.50 85.48 178.64 3576.78 3450.18 -7678.06 1896.68 5937715.40 560887.47 MWD+IFR-AK-CAZ-SC ' 9641.61 85.54 178.11 3584.22 3457.62 -7772.84 1899.36 5937620.65 560890.90 MWD+IFR-AK-CAZ-SC 9697.18 85.36 178.27 3588.63 3462.03 -7828.20 1901.11 5937565.30 560893.08 MWD+IFR-AK-CAZ-SC 9757.62 87.00 179.85 3592.66 3466.06 -7888.50 1902.10 5937505.03 560894.54 MWD+IFR-AK-CAZ-SC 9855.54 87.18 182.42 3597.63 3471.03 -7986.26 1900.17 5937407.26 560893.37 MWD+IFR-AK-CAZ-SC 9947.14 88.85 183.26 3600.80 3474.20 -8077.69 1895.63 5937315.80 560889.55 MWD+IFR-AK-CAZ-SC 10042.36 90.89 183.81 3601.02 3474.42 -8172.73 1889.76 5937220.74 560884.42 MWD+IFR-AK-CAZ-SC 10137.66 91.56 182.11 3598.98 3472.38 -8267.87 1884.84 5937125.56 560880.25 MWD+IFR-AK-CAZ-SC 10232.32 93.05 181.05 3595.18 3468.58 -8362.42 1882.23 5937031.01 560878.38 MWD+IFR-AK-CAZ-SC 10325.72 95.84 181.63 3587.94 3461.34 -8455.50 1880.05 5936937.92 560876.93 MWD+IFR-AK-CAZ-SC 10421.34 95.77 181.64 3578.27 3451.67 -8550.59 1877.34 5936842.82 560874.96 MWD+IFR-AK-CAZ-SC 10516.06 93.66 180.29 3570.48 3443.88 -8644.97 1875.75 5936748.44 560874.11 MWD+IFR-AK-CAZ-SC I 10611.75 89.89 177.75 3567.52 3440.92 -8740.57 1877.39 5936652.86 560876.50 MWD+IFR-AK-CAZ-SC 10707.74 89.77 178.29 3567.80 3441.20 -8836.51 1880.71 5936556.97 560880.57 MWD+IFR-AK-CAZ-SC 10802.17 90.02 178.49 3567.97 3441.37 -8930.90 1883.36 5936462.61 560883.96 MWD+IFR-AK-CAZ-SC 10896.86 89.89 180.61 3568.05 3441.45 -9025.58 1884.10 5936367.95 560885.44 MWD+IFR-AK-CAZ-SC 10992.03 88.90 181.15 3569.05 3442.45 -9120.73 1882.64 5936272.79 560884.72 MWD+IFR-AK-CAZ-SC i 11087.50 90.08 182.92 3569.90 3443.30 -9216.13 1879.25 5936177.38 560882.08 MWD+IFR-AK-CAZ-SC ~~ 11182.39 90.20 182.69 3569.67 3443.07 -9310.91 1874.61 5936082.58 560878.18 MWD+IFR-AK-CAZ-SC 11277.23 91.19 182.44 3568.52 3441.92 -9405.65 1870.36 5935987.82 560874.68 MWD+IFR-AK-CAZ-SC 11372.19 91.44 182.66 3566.34 3439.74 -9500.49 1866.14 5935892.96 560871.20 MWD+IFR-AK-CAZ-SC 11467.31 90.88 182.79 3564.42 3437.82 -9595.48 1861.62 5935797.94 560867.42 MWD+IFR-AK-CAZ-SC 11562.39 91.25 182.93 3562.65 3436.05 -9690.42 1856.88 5935702.97 560863.42 MWD+IFR-AK-CAZ-SC 11657.84 91.62 183.39 3560.26 3433.66 -9785.70 1851.62 5935607.67 560858.91 MWD+IFR-AK-CAZ-SC 11754.40 91.93 180.14 3557.27 3430.67 -9882.15 1848.64 5935511.20 560856.69 MWD+IFR-AK-CAZ-SC 11849.08 92.43 178.67 3553.67 3427.07 -9976.76 1849.63 5935416.62 560858.41 MWD+IFR-AK-CAZ-SC I! 11944.07 91.93 177.59 3550.05 3423.45 -10071.63 1852.72 5935321.79 560862.25 MWD+IFR-AK-CAZ-SC 12038.87 91.62 178.21 3547.12 3420.52 -10166.32 1856.19 5935227.14 560866.46 MWD+fFR-AK-CAZ-SC i, 12134.27 91.44 178.07 3544.57 3417.97 -10261.63 1859.29 5935131.86 560870.30 MWD+IFR-AK-CAZ-SC ~I 12228.08 91.56 177.83 3542.11 3415.51 -10355.35 1862.64 5935038.18 560874.39 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Date: 1/23/2007 Time: 13:31:27 ' Page: 4 ', Field: Kuparuk River Unit Co-ordinate(NF)Reference: Well: 1J-136, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-136: 126.6 Well: 1J-136 Section (VS) Reference: Well (O.OON,O.OOE;180.OOAzi) Wcllpath: 1J-136 Survey Calculation Method: Minimum Curvature Db: Oracle __ Survey MU Incl Azim TVD Sys TVD N/S EIW VIapN MapE Tool ft deg deg ft ft ft ft ft ft 12324.58 90.26 176.66 3540.58 3413.98 -10451.72 1867.28 5934941.85 560879.78 MWD+IFR-AK-CAZ-SC ~~ 12419.84 90.20 177.83 3540.20 3413.60 -10546.87 1871.86 5934846.75 560885.11 MWD+IFR-AK-CAZ-SC 12514.21 90.20 178.37 3539.87 3413.27 -10641.19 1874.99 5934752.47 560888.97 MWD+IFR-AK-CAZ-SC 12608.55 91.01 179.86 3538.87 3412.27 -10735.51 1876.45 5934658.18 560891.17 MWD+IFR-AK-CAZ-SC 12703.97 89.89 179.15 3538.12 3411.52 -10830.92 1877.27 5934562.78 560892.74 MWD+IFR-AK-CAZ-SC 12799.88 91.63 179.43 3536.85 3410.25 -10926.81 1878.46 5934466.91 560894.68 MWD+IFR-AK-CAZ-SC 12893.54 91.25 179.35 3534.50 3407.90 -11020.43 1879.46 5934373.31 560896.41 MWD+IFR-AK-CAZ-SC ~ 12988.92 90.57 179.18 3532.98 3406.38 -11115.79 1880.68 5934277.97 560898.38 MWD+IFR-AK-CAZ-SC 13084.60 90.70 179.68 3531.92 3405.32 -11211.46 1881.63 5934182.32 560900.08 MWD+IFR-AK-CAZ-SC 13179.95 91.07 180.36 3530.45 3403.85 -11306.80 1881.60 5934087.00 560900.79 MWD+IFR-AK-CAZ-SC 13275.22 90.82 180.90 3528.88 3402.28 -11402.05 1880.55 5933991.75 560900.49 MWD+IFR-AK-CAZ-SC ~ 13370.90 92.06 181.33 3526.47 3399.87 -11497.68 1878.69 5933896.12 560899.37 MWD+IFR-AK-CAZ-SC 13465.34 91.80 180.70 3523.29 3396.69 -11592.05 1877.02 5933801.74 560898.44 MWD+IFR-AK-CAZ-SC 13559.20 91.25 179.94 3520.79 3394.19 -11685.88 1876.49 5933707.93 560898.65 MWD+IFR-AK-CAZ-SC 13656.40 91.00 179.10 3518.89 3392.29 -11783.05 1877.31 5933610.77 560900.23 MWD+IFR-AK-CAZ-SC 13751.58 90.45 179.84 3517.68 3391.08 -11878.22 1878.19 5933515.62 560901.85 MWD+IFR-AK-CAZ-SC 13846.87 90.57 180.83 3516.83 3390.23 -11973.50 1877.63 5933420.35 560902.04 MWD+IFR-AK-CAZ-SC 13940.90 90.39 182.60 3516.05 3389.45 -12067.48 1874.82 5933326.36 560899.96 MWD+IFR-AK-CAZ-SC 14035.64 90.88 181.70 3515.00 3388.40 -12162.15 1871.26 5933231.67 560897.15 MWD+IFR-AK-CAZ-SC 14132.45 90.63 180.93 3513.72 3387.12 -12258.93 1869.04 5933134.89 560895.68 MWD+IFR-AK-CAZ-SC 14225.72 90.63 180.14 3512.69 3386.09 -12352.19 1868.17 5933041.64 560895.54 MWD+IFR-AK-CAZ-SC 14324.00 90.82 179.26 3511.45 3384.85 -12450.46 1868.69 5932943.38 560896.83 MWD+IFR-AK-CAZ-SC II 14418.92 90.51 179.28 3510.35 3383.75 -12545.36 1869.90 5932848.50 560898.78 MWD+IFR-AK-CAZ-SC i 14514.00 90.51 179.37 3509.50 3382.90 -12640.43 1871.02 5932753.45 560900.64 MWD+IFR-AK-CAZ-SC ~ 14608.15 90.94 180.47 3508.31 3381.71 -12734.57 1871.15 5932659.32 560901.51 MWD+IFR-AK-CAZ-SC 14703.51 92.43 179.60 3505.51 3378.91 -12829.89 1871.09 5932564.02 560902.20 MWD+IFR-AK-CAZ-SC 14798.31 90.45 180.08 3503.13 3376.53 -12924.65 1871.35 5932469.27 560903.20 MWD+IFR-AK-CAZ-SC 14893.25 90.63 179.13 3502.23 3375.63 -13019.58 1872.01 5932374.35 560904.60 MWD+IFR-AK-CAZ-SC 14986.90 89.83 179.68 3501.86 3375.26 -13113.23 1872.98 5932280.73 560906.31 MWD+IFR-AK-CAZ-SC 15084.17 90.33 179.47 3501.72 3375.12 -13210.49 1873.70 5932183.48 560907.79 MWD+IFR-AK-CAZ-SC 15179.74 90.39 180.11 3501.12 3374.52 -13306.06 1874.05 5932087.93 560908.89 MWD+IFR-AK-CAZ-SC 15274.86 89.64 180.89 3501.09 3374.49 -13401.18 1873.22 5931992.82 560908.80 MWD+IFR-AK-CAZ-SC 15369.92 89.96 181.65 3501.43 3374.83 -13496.21 1871.11 5931897.78 560907.44 MWD+IFR-AK-CAZ-SC 15465.64 90.26 181.57 3501.24 3374.64 -13591.89 1868.43 5931802.09 560905.50 MWD+IFR-AK-CAZ-SC 15560.68 89.71 180.15 3501.27 3374.67 -13686.92 1867.00 5931707.06 560904.82 MWD+IFR-AK-CAZ-SC 15655.97 90.51 180.08 3501.08 3374.48 -13782.21 1866.81 5931611.79 560905:37 MWD+IFR-AK-CAZ-SC 15751.73 90.57 179.50 3500.18 3373.58 -13877.96 1867.16 5931516.05 560906.47 MWD+IFR-AK-CAZ-SC 15846.26 90.70 180.61 3499.13 3372.53 -13972.49 1867.07 5931421.53 560907.12 MWD+IFR-AK-CAZ-SC III 15940.68 91.07 181.90 3497.68 3371.08 -14066.87 1865.00 5931327.15 560905.79 MWD+IFR-AK-CAZ-SC 16036.68 88.53 181.35 3498.01 3371.41 -14162.82 1862.28 5931231.18 560903.82 MWD+IFR-AK-CAZ-SC I _ + 16131.79 87.18 180.47 3501.57 3374.97 14257.85 1860.77 5931136.16 560903.05 MWD IFR-AK CAZ SC - - i i 16226.40 87.92 180.61 3505.61 3379.01 -14352.37 1859.88 5931041.64 560902.90 MWD+IFR-AK-CAZ-SC 16321.48 87.17 180.36 3509.69 3383.09 -14447.36 1859.07 5930946.66 560902.84 MWD+IFR-AK-CAZ-SC 16416.52 86.74 181.05 3514.74 3388.14 -14542.26 1857.91 5930851.77 560902.42 MWD+IFR-AK-CAZ-SC 16511.76 88.30 181.48 3518.86 3392.26 -14637.38 1855.80 5930756.64 560901.06 MWD+IFR-AK-CAZ-SC 16606.76 90.52 182.20 3519.84 3393.24 -14732.32 1852.75 5930661.69 560898.75 MWD+IFR-AK-CAZ-SC 16701.98 93.06 182.50 3516.86 3390.26 -14827.40 1848.85 5930566.58 560895.60 MWD+IFR-AK-CAZ-SC ~~ 16795.73 92.67 182.87 3512.18 3385.58 -14920.93 1844.47 5930473.03 560891.94 MWD+IFR-AK-CAZ-SC 16892.00 94.35 182.08 3506.28 3379.68 -15016.93 1840.32 5930377.01 560888.54 MWD+IFR-AK-CAZ-SC 16985.35 95.65 180.94 3498.15 3371.55 -15109.89 1837.87 5930284.05 560886.82 MWD+IFR-AK-CAZ-SC _ + 7. 4 MWD IFR AK CAZ SC 1 1.74 178.99 3491.88 3365.28 15206.81 1837.93 5930187.14 56088 6 - - - 7082.50 9 17178.49 90.63 178.67 3489.90 3363.30 -15302.76 1839.89 5930091.21 560890.35 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 1/23/2007 'time: 13:31:27 Page: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-136, True North Site: Kuparuk 1J Pad Vertical (T~'D) Reference: 1J-136: 126.6 R'ell: 1J-136 Section(VS)Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-136 Survey Calculation Method: Minimum Curvature Db: Oracle Sm-r°c~ MD lncl Azim TVD Sys TVD N/S ft deg deg ft ft ft 17273.83 92.06 180.09 3487.66 3361.06 -15398.0 17369.04 90.45 178.81 3485.58 3358.98 -15493.2 17460.64 87.85 177.75 3486.94 3360.34 -15584.7 17475.72 87.55 177.63 3487.54 3360.94 -15599.8 17507.00 ~ 87.55 177.63 3488.88 3362.28 -15631.06 E!W N1apN MapE Tool ft ft ft 1840.92 5929995.93 560892.13 MWD+IFR-AK-CAZ-SC 1841.83 5929900.77 560893.79 MWD+IFR-AK-CAZ-SC 1844.58 5929809.27 560897.25 MWD+IFR-AK-CAZ-SC 1845.19 5929794.22 560897.98 MWD+IFR-AK-CAZ-SC 1846.48 5929763.01 , 560899.51. 6 4 8 4 PROJECTED to TD Halliburton Company Survey Report __ - Company: ConocoPhillips Alaska Inc. Date: 1!23/2007 't'ime: 13:21:59 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1 J-136, Tr ue North Site: Kuparuk 1J Pad Ve rtical (TVD)Reference: 1J-136PB1: 126.6 Wrll: 1J-136 Section (VS) Reference: Well (O.OON,O.O OE,180.OOAzi) Wellpath: 1J-136PB1 Su rvey Calculation Method: Minimum Curva ture Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~ Well: 1 J-136 Slot Name: Well Position: +N/-S -543.14 ft Northing: 5945377.64 ft Latitude: 70 15 40.916 N +E/-W 136.78 ft Easting : 558930.95 ft Longitude: 149 31 25.027 W Position Uncertainty: 0.00 ft Wellpath: 1J-136PB1 Drilled From: Well Ref. Point 500292333170 Tie-on Depth: 45.50 ft Current Datum: 1 J-136P81: Height 126.60 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 45.50 0.00 0.00 180.00 _~ Survey Program for Definitive Wellpath j Date: 11/18/2004 Validated: No V ersion: 3 Actual From To Survey Toolcode Tool Name ft ft 120.00 815.00 1J-136PB1 gyro (120.00-815.00) C B-GYRO-SS Camera based gyro single shot 848.68 8786.52 1J-136PB1 (848.68- 8786.52) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey iV1D Inc! Azim TVD Sys TVD N/S F,IW MapN iv1apE Tool ft deg deg ft ft ft ft _ ft ft - _ __ _ - _ 45.50 0.00 0.00 45.50 -81.10 0.00 0.00 5945377.64 558930.95 TIE LINE 120.00 0.20 47.82 120.00 -6.60 0.09 0.10 5945377.73 558931.05 CB-GYRO-SS 171.00 0.14 285.78 171.00 44.40 0.16 0.10 5945377.80 558931.05 CB-GYRO-SS 265.00 0.27 139.61 265.00 138.40 0.03 0.14 5945377.67 558931.09 CB-GYRO-SS 352.00 2.78 197.00 351.96 225.36 -2.15 -0.35 5945375.49 558930.62 CB-GYRO-SS i 450.00 6.34 203.00 449.64 323.04 -9.40 -3.16 5945368.21 558927.87 CB-GYRO-SS I 536.00 7.46 210.17 I 535.02 408.42 -18.60 -7.82 5945358.98 558923.28 CB-GYRO-SS I 635.00 9.75 215.20 632.90 506.30 -31.01 -15.88 5945346.51 558915.31 CB-GYRO-SS 735.00 12.62 218.15 730.99 604.39 -46.52 -27.51 5945330.91 558903.80 CB-GYRO-SS 815.00 14.54 214.61 808.75 682.15 -61.66 -38.62 5945315.68 558892.82 CB-GYRO-SS ~, 848.68 14.47 210.72 841.36 714.76 -68.76 -43.17 5945308.55 558888.32 MWD+IFR-AK-CAZ-SC 942.92 13.87 206.23 932.73 806.13 -89.01 -54.18 5945288.21 558877.48 MWD+IFR-AK-CAZ-SC 1037.30 17.05 197.44 1023.70 897.10 -112.37 -63.33 5945264.79 558868.51 MWD+IFR-AK-CAZ-SC 1134.76 21.29 193.44 1115.73 989.13 -143.23 -71.73 5945233.87 558860.35 MWD+IFR-AK-CAZ-SC 1228.85 25.03 191.05 1202.23 1075.63 -179.39 -79.51 5945197.65 558852.85 MWD+IFR-AK-CAZ-SC 1324.31 29.33 189.97 1287.13 1160.53 -222.26 -87.44 5945154.73 558845.26 MWD+IFR-AK-CAZ-SC 1419.52 33.46 185.70 1368.39 1241.79 -271.37 -94.08 5945105.57 558839.00 MWD+IFR-AK-CAZ-SC 1515.12 36.71 182.56 1446.62 1320.02 -326.16 -97.98 5945050.76 558835.54 MWD+IFR-AK-CAZ-SC 1609.68 42.44 181.81 1519.47 1392.87 -386.33 -100.25 5944990.57 558833.73 MWD+IFR-AK-CAZ-SC 1704.86 45.67 181.69 1587.87 1461.27 -452.47 -102.27 5944924.42 558832.23 MWD+IFR-AK-CAZ-SC i 1798.73 49.25 182.85 I 1651.32 1524.72 -521.57 -105.03 5944855.31 558830.02 MWD+IFR-AK-CAZ-SC ii 1895.85 53.54 180.56 1711.91 1585.31 -597.41 -107.24 5944779.47 558828.40 MWD+IFR-AK-CAZ-SC 1990.76 56.49 178.87 1766.33 1639.73 -675.15 -106.83 5944701.74 558829.41 MWD+IFR-AK-CAZ-SC 2085.78 62.49 175.78 1814.55 1687.95 -756.87 -102.95 5944620.06 558833.94 MWD+IFR-AK-CAZ-SC 2180.15 65.96 175.41 1855.58 1728.98 -841.59 -96.42 5944535.40 558841.13 MWD+IFR-AK-CAZ-SC 2275.63 70.43 172.88 1891.05 1764.45 -929.74 -87.35 5944447.33 558850.89 MWD+IFR-AK-CAZ-SC 2370.17 75.31 170.62 1918.89 1792.29 -1019.11 -74.36 5944358.07 558864.57 MWD+IFR-AK-CAZ-SC 2466.49 77.31 168.78 1941.68 1815.08 -1111.18 -57.63 5944266.15 558882.03 MWD+IFR-AK-CAZ-SC 2562.02 77.65 165.14 1962.40 1835.80 -1202.01 -36.59 5944175.49 558903.77 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: _ 1/23/2007 Time: 13:21:59 Page: 2 ' Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-136, True North ' Site: Kuparuk 1J Pad Vertical (fVD) Reference: 1J-136PB1: 126.6 Well: 1J-136 Section (~'S)Reference: Well (O.OON,O.OOE,180.OOAzi) ~~ellpath: 1J-136PB1 Sun~ey Calculation Mcthod: Minimum Curvature I)h: Oracle Suncv >lU Incl ~iim TVD SysTVD N/S E/1V MapN MapE Tool ft deg deg ft ft ft ft ft ft ', 2656.89 78.08 161.08 1982.35 1855.75 -1290.74 -9.64 5944086.99 558931.41 MWD+IFR-AK-CAZ-SC 2751.03 77.04 158.83 2002.63 1876.03 -1377.10 21.86 5944000.89 558963.58 MWD+IFR-AK-CAZ-SC 2847.52 74.33 155.61 2026.49 1899.89 -1463.28 58.04 5943914.99 559000.43 MWD+IFR-AK-CAZ-SC 2942.22 75.53 155.39 2051.11 1924.51 -1546.49 95.96 5943832.09 559039.00 MWD+IFR-AK-CAZ-SC 3037.83 74.33 155.49 2075.97 1949.37 -1630.46 134.33 5943748.44 559078.02 MWD+IFR-AK-CAZ-SC 3133.17 74.30 156.45 2101.75 1975.15 -1714.29 171.71 5943664.91 559116.05 MWD+IFR-AK-CAZ-SC 3227.45 71.25 155.98 2129.66 2003.06 -1796.69 208.02 5943582.81 559153.00 MWD+IFR-AK-CAZ-SC 3322.39 77.47 155.05 2155.25 2028.65 -1879.84 245.90 5943499.96 559191.53 MWD+IFR-AK-CAZ-SC 3416.75 76.91 154.82 2176.17 2049.57 -1963.19 284.88 5943416.93 559231.16 MWD+IFR-AK-CAZ-SC 3466.52 76.15 154.70 2187.76 2061.16 -2006.97 305.52 5943373.31 559252.14 MWD+IFR-AK-CAZ-SC 3552.93 74.51 155.23 2209.64 2083.04 -2082.71 340.89 5943297.87 559288.10 MWD+IFR-AK-CAZ-SC 3647.71 75.21 157.64 2234.40 2107.80 -2166.56 377.46 5943214.31 559325.32 MWD+IFR-AK-CAZ-SC 3742.63 75.74 157.42 2258.21 2131.61 -2251.47 412.58 5943129.68 559361.10 MWD+IFR-AK-CAZ-SC 3838.51 75.42 159.32 2282.09 2155.49 -2337.79 446.81 5943043.65 559396.00 MWD+IFR-AK-CAZ-SC 3933.33 75.40 160.21 2305.97 2179.37 -2423.88 478.55 5942957.81 559428.41 MWD+IFR-AK-CAZ-SC 4027.56 77.96 161.69 2327.68 2201.08 -2510.55 508.47 5942871.39 559459.00 MWD+IFR-AK-CAZ-SC I 4123.78 77.54 162.94 2348.10 2221.50 -2600.13 537.03 5942782.04 559488.26 MWD+IFR-AK-CAZ-SC 4218.48 76.69 163.15 2369.21 2242.61 -2688.43 563.95 5942693.96 559515.87 MWD+IFR-AK-CAZ-SC 4314.18 75.58 163.58 2392.15 2265.55 -2777.46 590.55 5942605.16 559543.16 MWD+IFR-AK-CAZ-SC 4408.86 75.71 163.49 2415.62 2289.02 -2865.42 616.55 5942517.41 559569.84 MWD+IFR-AK-CAZ-SC 4503.15 76.55 164.02 2438.22 2311.62 -2953.30 642.16 5942429.74 559596.14 MWD+IFR-AK-CAZ-SC 4600.43 76.13 164.36 2461.20 2334.60 -3044.25 667.91 5942339.00 559622.60 MWD+IFR-AK-CAZ-SC 4694.51 75.86 164.53 2483.97 2357.37 -3132.19 692.39 5942251.26 559647.76 MWD+IFR-AK-CAZ-SC , 4789.98 74.97 165.83 2508.01 2381.41 -3221.51 716.02 5942162.14 559672.09 MWD+IFR-AK-CAZ-SC 4885.79 76.74 165.10 2531.42 2404.82 -3311.44 739.34 5942072.41 559696.11 MWD+IFR-AK-CAZ-SC 4981.19 75.05 165.10 2554.67 2428.07 -3400.85 763.13 5941983.20 559720.60 MWD+IFR-AK-CAZ-SC ~I 5075.80 75.79 165.70 2578.49 2451.89 -3489.45 786.21 5941894.78 559744.37 MWD+IFR-AK-CAZ-SC 5171.78 76.40 165.52 2601.55 2474.95 -3579.70 809.37 5941804.73 559768.22 MWD+IFR-AK-CAZ-SC 5265.59 74.53 166.26 2625.09 2498.49 -3667.76 831.50 5941716.85 559791.05 MWD+IFR-AK-CAZ-SC 5361.20 74.24 165.03 2650.83 2524.23 -3756.96 854.33 5941627.84 559814.57 MWD+IFR-AK-CAZ-SC 5457.33 74.26 164.10 2676.92 2550.32 -3846.15 878.96 5941538.86 559839.89 MWD+IFR-AK-CAZ-SC 5552.50 77.11 162.26 2700.45 2573.85 -3934.40 905.65 5941450.82 559867.27 MWD+IFR-AK-CAZ-SC , 5647.52 76.07 162.59 2722.49 2595.89 -4022.51 933.55 5941362.94 559895.86 MWD+IFR-AK-CAZ-SC 5742.83 75.16 164.48 2746.17 2619.57 -4111.04 959.72 5941274.63 559922.72 MWD+IFR-AK-CAZ-SC 5836.32 76.20 162.83 2769.30 2642.70 -4197.96 985.22 5941187.92 559948.89 MWD+IFR-AK-CAZ-SC 5932.78 76.49 163.50 2792.07 2665.47 -4287.68 1012.36 5941098.43 559976.74 MWD+IFR-AK-CAZ-SC ij 6028.11 78.25 163.26 2812.91 2686.31 -4376.81 1038.97 5941009.51 560004.04 MWD+IFR-AK-CAZ-SC 6123.03 78.56 164.09 2831.99 2705.39 -4466.04 1065.11 5940920.50 560030.87 MWD+IFR-AK-CAZ-SC 6218.26 77.83 164.18 2851.47 2724.87 -4555.71 1090.59 5940831.04 560057.05 MWD+IFR-AK-CAZ-SC 6312.97 78.26 164.81 2871.09 2744.49 -4644.99 1115.36 5940741.96 560082.51 MWD+IFR-AK-CAZ-SC 6407.99 78.39 165.64 2890.32 2763.72 -4734.97 1139.09 5940652.18 560106.94 MWD+IFR-AK-CAZ-SC 6502.97 78.14 164.05 2909.64 2783.04 -4824.73 1163.40 5940562.63 560131.95 MWD+IFR-AK-CAZ-SC 6598.32 76.41 164.52 2930.64 2804.04 -4914.25 1188.59 5940473.31 560157.84 MWD+IFR-AK-CAZ-SC 6693.68 76.48 163.31 2952.99 2826.39 -5003.33 1214.27 5940384.45 560184.22 MWD+IFR-AK-CAZ-SC 6788.75 77.51 162.41 2974.39 2847.79 -5091.84 1241.57 5940296.16 560212.21 MWD+IFR-AK-CAZ-SC 6885.02 77.09 162.36 2995.55 2868.95 -5181.35 1269.99 5940206.88 560241.33 MWD+IFR-AK-CAZ-SC i 6980.08 75.74 161.32 3017.88 2891.28 -5269.15 1298.79 5940119.32 560270.81 MWD+IFR-AK-CAZ-SC 7073.70 76.06 161.10 3040.69 2914.09 -5355.11 1328.04 5940033.60 560300.72 MWD+IFR-AK-CAZ-SC ~' 7169.70 75.37 159.78 3064.37 2937.77 -5442.77 1359.18 5939946.20 560332.55 MWD+IFR-AK-CAZ-SC 7264.91 75.32 160.47 3088.46 2961.86 -5529.39 1390.49 5939859.83 560364.54 MWD+IFR-AK-CAZ-SC 7360.01 75.91 160.13 3112.09 2985.49 -5616.12 1421.55 5939773.35 560396.26 MWD+IFR-AK-CAZ-SC 7455.22 75.95 159.52 3135.24 3008.64 -5702.81 1453.40 5939686.93 560428.79 MWD+IFR-AK-CAZ-SC !, Halliburton Company Survey Report Company: ConocoPhillips Alaskalnc. Field: Kuparuk Riv er Unit Site Ku paruk 1J Pad Nell: 1 J -136. R~'etipath: 1J -1?6P81 Sunev --- - MD lncl Azim TVD Sys TVD N/S ft deg deg ft ft ft 7548.91 75.50 160.57 3158.34 3031.74 -5788.1 7645.28 75.37 160.94 3182.57 3055.97 -5876.2 7738.81 74.66 160.16 3206.76 3080.16 -5961. 7835.65 73.99 161.81 3232.92 3106.32 -6049. 7930.56 74.02 161.73 3259.08 3132.48 -6136. 8025.73 77.06 160.74 3282.84 3156.24 -6223. 8119.36 76.89 161.17 3303.94 3177.34 -6309. 8216.42 75.28 162.91 3327.28 3200.68 -6399.2 8312.10 i 76.06 162.35 3350.96 3224.36 -6487. j 8407.06 74.58 162.16 3375.03 3248.43 -6575.2 8502.36 76.41 162.53 3398.90 3272.30 -6663.1 8598.36 75.80 162.40 3421.95 3295.35 -6752. 8693.47 76.14 165.01 3445.01 3318.41 -6840. 8786.52 79.16 168.13 3464.91 3338.31 -6928. 8858.00 79.16 168.13 3478.36 3351.76 -6997. Date: 1!23!2007 Time: 13:21:59 Fage: 3 Co-or dinate(NE) Reference: WefI:1J-136,. T rue North Vertical (TVD)Rcfcrcncc: 1J-136PB1:126.6 Sectio n (VS)Reference: Well (O.OON,OOOE;180.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle E/W ><1apN J1apE Tool ft ft ft - 5 - _--- 1484.39 - 5939601.84 560460.44 MWD+IFR-AK-CAZ-SC 1 1515.13 5939514.03 560491.87 MWD+IFR-AK-CAZ-SC 0 1545.21 5939429.08 560522.62 MWD+IFR-AK-CAZ-SC 5 1575.59 5939341.19 560553.68 MWD+IFR-AK-CAZ-SC 1 1604.13 5939254.76 560582.90 MWD+IFR-AK-CAZ-SC 5 1633.78 5939167.76 560613.22 MWD+IFR-AK-CAZ-SC 8 1663.55 5939081.78 560643.66 MWD+IFR-AK-CAZ-SC 9 1692.60 5938992.41 560673.41 MWD+IFR-AK-CAZ-SC 6 1720.28 5938904.16 560701.78 MWD+IFR-AK-CAZ-SC 5 1748.27 5938816.90 560730.45 MWD+IFR-AK-CAZ-SC 6 1776.25 5938729.22 560759.12 MWD+IFR-AK-CAZ-SC 2 1804.33 5938640.59 560787.89 MWD+IFR-AK-CAZ-SC 8 1830.21 5938552.25 560814.46 MWD+IFR-AK-CAZ-SC 8 1851.31 5938464.03 560836.24 MWD+IFR-AK-CAZ-SC 8 1865.75 5938395.45 560851.22 PROJECTED to TD 4 5 2 4 6 7 0 5 9 6 • ~. - Description of Casin Well: 1J-136 ConocoPhillips Slotted and Blank Liner Date: 12/10/2006 A~a~~. ~^~ Supervisors: Fred Herbert /Scott Heim Rig: Doyon is DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 9186.08 9186.08 FINAL DETAIL 9186.08 9186.08 5" DP to Surface =_> 9186.08 Liner Runnin Tool 5" Does not sta in hole 10.82 9186.08 "HRD" ZXP Liner To Packer 9-5/8" 7.50" X 8.43" 18.52 9196.90 "RS" Packoff Seal Ni le 7.00" 6.19" ID x 7.65" OD 4.09 9215.42 FlexLock Liner Han er 7"x 9-5/8" 6.23" X 8.34" 7.75 9219.51 XO Bushin 4.90" ID, 7.67" OD 1.72 9227.26 190-47 Casin Seal Bore Ext. 4.75"ID x 6.31" OD 19.64 9228.98 Pu Jt. - 5-1/2", 15.5 f, L-80, H dril 521 4.15 9248.62 Jts t92to 203 t2 Jts 5-1 /2",15.5 f, L-80, H dril 521 BTCM Blank Casin 497.18 9252.77 Jts 191 to 191 t .ns 5-1 /2",15.5 f, L-80, H dril 521 BTCM Slotted Casin 40.80 9749.95 Jts 19o to t90 ~ Jts 5-1 /2".15.5 f, L-80. H dril 521 BTCM Blank Casin 38.17 9790.75 Jts tas to 189 ! Jts 5-1 /2".15.5 f, L-80. H dr~l 521 BTCM Slotted Casin 40.81 9828.92 Jts t88 ro 188 ~ .its 5-1 /2",15.5 f, L-80. H car,i 521 BTCM Blank Casin 41.67 9869.73 Jts 187 to 18 ? .lcs 5-1/2".15.5 f, L-80, H <!-:! X21 BTCM Slotted Casin 37.94 9911.40 Jts t86to tas ? .!!-. 5-112",15.5 f, L-80, Hv, `=TCM Blank Casin 41.05 9949.34 Jts 185 to t85 ~ .~;s 5-1 /2".15.5 p f, L-80. t'. -BTCM Slotted Casin 41.67 9990.39 Jts 184 to 184 t :,;~. 5-112".15.5 f. L-8f' ?TCM Blank Casin 41.44 10032.06 Jts 183 to 183 t Jts 5-1 i2".15.5 f, '- ? BTCM Slotted Gasin 41.77 10073.50 Jts 182 to t82 t Jts 5-1/2",15.5 po' .` ~ CM Blank Casin 41.64 10115.27 Jts t81 to 181 '. Jts 5-1 /2",15.5 ~ rii 521 BTCM Slotted Casin 41.73 10156.91 Jts t80 to 18 ' Jts 5-1 /2",15.5 ~ aril 5'21 B i CM Blank Casin 40.19 10198.64 5-112" H dril 521 box x 4-1/2" BTC in Crossover 1.60 10238.83 Jts 172 to 179 a Jt> 5-1/2", 15.5 f, L-80, BTC Blank Casin 317.69 10240.43 Jts t70 to 171 5-1 /2",15.5 f, L-80. BTC Slotted Casin 84.77 10558.12 Jts tssto tss ! .!cs 5-1/2", 15.5 f, L-80, BTC Blank Casin 37.90 10642.89 Jts 168 to 16s ; .;~~: 5-1 /2",15.5 f, L-80, BTC Slotted Casin 42.24 10680.79 Jts ts7tots 5-1/2", 15.5 f, L-8Q, BTC Blank Casin 39.43 10723.03 Jts 166 to t66 ~ ..~~ 5-1 /2",15.5 f, L-80. BTC Slotted Casin 43.55 10762.46 Jts 165 to 165 ; .:;~ 5-1/2", 15.5 f, L-80, BTC Bla k Casin 39.53 10806.01 Jts 76a to t64 ; ~!5 5-112",15.5 f, L-80, BTC SioY€ed Casin 43.33 10845.54 Jts ts3 to ts3 5-1/2'>,,i15.5 f, L-80, BTC Blank Casin 42.66 10888.87 Jts 162 to 162 ;-1;2",15.5 f. L-80, BTC Slotted Casin 42.40 10931.53 Jts 161 to 161 5-1/2", 15.5 f, L-80, BTC Blank Casin 39.31 10973.93 Jts 16o to 160 5-1 /2",15.5 f, L-80, BTC Slotted Casin 42.96 11013.24 Up Wt 275K Dn Wt ???K Block Wt 70K Used Run-N-Seal thread com ound on all connections. Rot Wt t a,r, Drifted casing to 4.833" w/ teflon rabbit. Liner Wt %4 ~ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 152 to 159 s Jts 5-1/2",15.5 f, L-80, BTC Blank Casin 31s.so 11056.20 Jts 151 to 151 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 43.49 11371.80 Jts 150 to 15 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 39.29 11415.26 Jts 149 to 14 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 43.56 11454.55 Jts 148 to 14 1 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin 36.39 11498.11 Jts 1a7to 1a 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin a3.a7 11537.50 Jts tas to 1a 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 33.77 11580.97 JtS 145 to 14 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin a2.sa 11614.74 Jts 144 to 144 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 40.15 11657.68 Jts tai to tai 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin x3.55 11697.83 Jts 142 to 142 1 Jts 5-ir2" 15.5 f L-80 BTC Blank Casin 37.78 11741.38 Jts 141 to 141 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin a2.71 11779.16 Jts 133 to 140 e Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 31a.71 11821.87 Jts 131 to 132 2 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin 87.05 12136.58 Jts 130 to 130 1 Jts 5-1/2", 15.5 , L-80, BTC Blank Casin 37.85 12223.63 Jts 129 to 129 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin 43.48 12261.48 Jts 128 to 128 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 40.59 12304.96 Jts 127 to 12 1 Jts 5-1l2",15.5 f, L-80, BTC Slotted Casin 43.76 12345.55 Jts 126 to 126 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin ao.1a 12389.31 Jts 125 to 125 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 3a.7a 12429.45 Jts 124 to 124 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 3s.ss 12468.19 Jts 123 to 123 1 Jts 5-1l2",15.5 f, L-80, BTC Slotted Casin 43.23 12507.18 Jts 122 to 122 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin x1.31 12550.41 Jts 121 to 121 1 Jts 5-1l2",15.5 f, L-80, BTC Slotted Casin 43.53 12591.72 Jts 112 to 120 9 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin 353.95 12635.25 Jts 111 to 111 1 Jts 5-112",15.5 f, L-80, BTC Slotted Casin 39.78 12989.20 Jts 11o to 110 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 3s.as 13028.98 Jts losto 1os 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 43.15 13068.46 Jts loato 1os 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 39.59 13111.61 Jts 107 to 10 1 Jts 5-1 /2",155 f, L-80, BTC Slotted Casin aos3 13151.20 Jts losto 106 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 39.15 13192.13 Jts 105 to 105 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin ao.53 13231.28 Jts 104 to 104 1 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin ao.o2 13271.81 Jts 103 to 103 1 Jts 5-112",15.5 f, L-80 BTC Slotted Casin a1 s1 13311.83 Jts 1o2to 102 1 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin 41.67 13353.64 Jts 101 to 101 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 43.56 13395.31 Jts 93 to 100 8 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 313.54 13438.87 Jts st to s2 2 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 80.77 13752.41 Remarks: r r Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts so to so 1 Jts 5-1/2" 15.5 f, L-80, BTC Blank Casin ao.12 13833.18 Jts s9 to ss 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 42.34 13873.30 Jts 8a to as 1 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin aos3 13915.64 Jts a7 to a7 1 Jts 5-112",15.5 f, L-80, BTC Slotted Casin 43.38 13956.27 Jts as to ss 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 37.75 13999.65 Jts s5 to 85 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin a2.7s 14037.40 Jts 8a to 84 1 Jts 5-1 /2", 15.5 f, L-80, BTC Blank Casin 36.43 14080.16 Jts s3 to e3 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 43.47 14119.59 Jts a2 to a2 1 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin 3ssa 14163.06 Jts 81 to 81 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 42.77 14203.00 Jts 73 to 80 8 Jts 5-1r2", 15.5 f L-80 BTC Blank Casin 31s.is 14245.77 Jts 72 to 72 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin 43.31 14561.96 Jts 71 to 71 1 Jts 5-1l2", 15.5 f, L-80, BTC Blank Casin 39.55 14605.27 Jts 70 to 70 1 Jts 5-112",15.5 f, L-80, BTC Slotted Casin 40.58 14644.82 Jts ss to s9 1 Jts 5-1/2",15.5 f L-80, BTC Blank Casin 43.32 14685.40 Jts 68 to 68 1 Jts 5-1l2",15.5 f, L-80, BTC Slotted Casin 43.37 14728.72 Jts s7 to s7 1 Jts 5-1l2", 15.5 f L-80, BTC Blank Casin 34.34 14772.09 Jts ss to 66 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin ao.35 14810.43 Jts 65 to 65 1 Jts 5-1/2" 15.5 f, L-80, BTC Blank Casin 40.52 14850.78 Jts 84 to 64 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 41.63 14891.30 Jts s3 to s3 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 43.16 14932.93 Jts s2 to s2 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin 43.50 14976.09 Jts 54 to 61 s Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 327.90 15019.59 Jts 52 to 53 2 Jts 5-112",15.5 f, L-80, BTC Slotted Casin 84.25 15347.49 Jts 51 to 51 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 36.54 15431.74 Jts 50 to 50 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin x3.35 15471.28 Jts as to as 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin ao.io 15514.63 Jts 48 to 48 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 43.18 15554.73 Jts a7 to a7 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 3s.5o 15597.91 Jts 46 to 48 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin 43.34 15637.41 Jts 45 to 45 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 36.65 15680.79 Jts a4 to as 1 Jts 5-1l2",15.5 f, L-80, BTC Slotted Casin 43.54 15720.74 Jts a3 to 43 1 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin 41.87 15764.28 Jts 42 to 42 1 Jts 5-1 /2",15.5 f, L-80 BTC Slotted Casin x1.77 15806.15 Jts 34 to 41 s Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 317.48 15847.92 Jts 32 to 33 2 Jts 5-1l2",15.5 f, L-80, BTC Slotted Casin sa.7s 16165.40 Jts 31 to 31 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 37.83 16250.19 Jts 3o to 30 1 Jts 5-1 /2",15.5 f, L-80, BTC Slotted Casin 43.55 16288.02 Remarks: Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 4 LENGTH TOPS Jts 29 to 29 1 Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin ao.oo 16331.57 Jts 2s to 28 ~ Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin a3.32 16371.57 Jts 13 to 27 t 5 Jts 5-1/2",15.5 f, L-80, BTC Blank Casin ssa.as 16414.89 Jts 12 to 12 ~ Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin 43.53 17003.35 Jts t t to t ~ ~ Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin 39.75 17046.88 Jts to to to 1 Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin ao.oo 17086.63 Jts s to 9 ~ Jts 5-1/2", 15.5 f, L-80, BTC Blank Casin a2.sa 17126.63 Jts8to8 t Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin a3.fs 17169.47 Jts 7 to 7 t Jts 5-1/2", 15.5 f, L-80, B7C Blank Casin 4l?.45 17212.63 Jts s to s t Jts 5-112",15.5 f, L-80, BTC Slotted Casin x2.97 17253.08 Jts 3 to 5 3 Jts 5-1/2" 15.5 f L-80 BTC Blank Casin i i 7.3a 17296.05 Jts 2 to 2 t Jts 5-1/2",15.5 f, L-80, BTC Slotted Casin a2.0~ 17413.39 Jts 1 to 1 t Jts 5-1/2",15.5 f, L-80, BTC Blank Casin 37.66 17455.46 5-112" BTC Silver Bullet Float Shoe ~.as 17493.12 17495.00 TD 8 1/2" hole ~ 17,507' MD / 3,489' TVD 17495.00 5-1/2" Shoe ~ 17,495' MD / 3,489' TVD 17495.00 17495.00 Intermediate 9- 5/8 Shce ~ 9,729' MD! 3,591' TVD 17495.00 Total Parts used: 13 S iro liders,198 sto rin s & 17495.00 183 H droFORM Centralizers. 17495.00 Run 1 s iro lider eve other ' . Floatin w/ sto son 17495.00 center of ' s Jt 196 ,198, 200, 202 17495.00 Run 1 H droFORM r't floatin with a sto rin in 17495.00 center of each ' . f/ Jt 2 thru Jt 195 17495.00 17495.00 To of D Sand =9081' MD 17495.00 To of ZXP =116' below D Sand to 17495.00 Constrictors Set De the 1 17411'-17344' 17495.00 2 16934'-16413' 17495.00 3 16134'-15853' 17495.00 4 15342'-15054' 17495.00 5 14532'-14255' 17495.00 6 13739'-13448' 17495.00 7 12939'-12654' 17495.00 8 12130'-11849' 17495.00 9 11337'-11059' 17495.00 10 10532'-10255' 17495.00 Remarks: Rana total of 20 constrictors. ~ ~ Time Logs Date From To Dur S. Depth --- E. Depth Phase Code_ Subcode T __ COM __ _ 'i 11/18/2006 06:00 09:30 3.50 MIRU MOVE MOB P Continue rig up air, steam, hydraulic, and water lines in rig. Lay pit liner and matting boards & back in, position rockwasher module with truck. Install cuttings tanks and rig up steam lines. Continue rig up lines and prepare rig for acceptance. Install walkaround, and install berms with pit liner. Rig ready to take on fluid. Rig accepted @ 0930 HRS. 09:30 12:00 2.50 MIRU MOVE RURD P Take on 580 BBLS pre mixed spud mud to pit system. Mud = 8.7 PPG, Visc = 80. Install Riser on Hydril, install flowline, fill up line & turnbuckles. Load pipe shed with 114 joints of 5" drill pipe for surface hole. Load MWD & DD tools in shed for BHA #1. 12:00 18:00 6.00 MIRU DRILL RURD P Continue load BHA #1 in pipe shed. Allow to warm up and obtain straps & measurements. Install 30' section of diverter line to knife valve assembly. Install shaker screens for spud. Begin picking up 5" DP from pipe shed, making stands and racking back in derrick. Crew Chan e 18:00 20:30 2.50 MIRU DRILL RURD P Continue pick up 5" drill pipe from pipe shed. Drift DP to 2.45" drift. Picked up a total of 114 'oints. 20:30 21:30 1.00 MIRU DRILL RURD P Continue pick up 20 joints of 5" HWDP from shed and 6 1/4" Dailey drilling 'ars. 21:30 22:30 1.00 MIRU DRILL RURD P Re-route Koomey lines. Position stand in cellar, adjust flowline in riser ,and unwind Derrick climber line. 22:30 23:45 1.25 MIRU WELCT OTHR P Perform Diverter test with last stand hanging in Top Drive. Observed 22 seconds for Knife valve to fully open and 35 seconds for Annular to close. Perform draw down test on Accumulator. Observed first 200 PSI increase after closing in 42 seconds, and full pressure to 3000 PSI on Koomey in 3.45 minutes. Obse4rved average pressur on 5 nitrogen bottles @ 2250 PSI. Witness of test waived b AOGCC re -Chuck Sheve 23:45 00:00 0.25 MIRU RIGMN RGRP P Bring new saver sub to rig floor. Clean & clear floor area. Obtain RKB measurements and record same. 11/19/2006 00:00 01:45 1.75 MIRU RIGMN SVRG P Service & grease crown section sheaves. Change out saver sub. Install 4 1/2" IF Saver sub. 01:45 02:15 0.50 MIRU DRILL PULD P Pull bit & tools to rig floor. Inspect & au a bit. I Time Logs -- - -- Date Frorn_ To Dur S De th E. Depth Phase Code Subcode _T .COM 11!19/2006 02:15 02:30 0.25 MIRU DRILL SFTY P Held PJSM with crew ,DD's &MWD rep. Discuss safety issues and procedure for making up BHA #1, spudding well, and rigging up gyro crew. 02:30 04:00 1.50 SURFA DRILL PULD P Make up BHA #1. Make up Hughes MX-1 Milltooth bit with 1x13, 3x20 jets for a TFA of 1.050 sq in. (1.38'), 8" Sperrydrill lobe 4/5 -5.3 stage, 1.83 deg bend in motor. Note: motor rev/gal _ .26 (28.84'), and 8" Welded blade stabilizer (4.88'), 8" Non Mag pressure drop (2.01'), 8" MWD directional (25.54'), 8" Non Mag Float sub (2.16'), 8" Non Mag UBHO Sub (2.51'), Bottle neck XO 2.48' . 04:00 04:30 0.50 SURFA DRILL PULD P Pull sheaves to floor and rig up Halliburton GYRO unit. 04:30 05:00 0.50 SURFA DRILL OTHR P Flood conductor with spud mud. Check all lines, and pumps. Check Diverter system for leaks. Good returns & all looks ood. 05:00 06:00 1.00 SURFA DRILL OTHR T Tag bottom @ 120' RKB load shoulder to rotary table = 41.20'. GL RKB = 45.50'. Roll Pumps & observe pumps kicking off line. Rack 1 stand back, blow down Top drive & lines. Call for Rig Electrician. Check connections, retry pumps, pumps back on line. Pick up 1 stand. Crew Chan e 06:00 12:00 6.00 0 341 SURFA DRILL DDRL P Directional drill 16" Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 0' - 341' MD (341') TVD = 341'. Total hrs on bit= 2.91 hrs, Jar hours = 2.91 hrs, ADT = 2.91 HRS, ART 1.52 hrs, AST 1.39 hrs, WOB 10-20K, 50 RPM, Motor RPM - 130, 500 GPM's @ 1100 psi on bottom and 1000 psi off bottom. Torque = 3K ft-Ibs on botttom and 2K ft-Ibs off bottom. P/U = 105K, S/O = 98K, ROT WT= 100K . AVG Gas observed = 42.2 Units. Mud Wt = 9.1 PPG, Visc = 300 Survey @ 265.0 MD 265' TVD, INC = .27 DEG, AZ = 139.61 DEG. Use Halliburton Gyro surve . _ ~ _ ~ __ - _ _~ --. ~ _..__._~~~ ~ o~ ~ • Time Logs __ Date From _ To Dur S De th E. De th Phase Code Subcod e T COM ' 11/19/2006 12:00 18:00 6.00 341 801 SURFA DRILL _ _ DDRL P Directional drill 16" Surface hole w/ 8" SperryDril- 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 341' - 801 MD (460') ND = 794'. Total hrs on bit= 6.33 hrs, Jar hours = 6.33 hrs, ADT = 3.42 HRS, ART 1.87 HRS, AST 1.55 HRS, WOB 25-30K, 50 RPM, Motor RPM - 148, 570 GPM's @ 1700 psi on bottom and 1500 psi off bottom. Torque = 5K ft-Ibs on botttom and 2K ft-Ibs off bottom. P/U = 121 K, S/O = 119K, ROT WT= 120K .AVG Gas observed = 22 Units. Mud Wt = 9.1 PPG, Visc = 300 Survey @ 735.0 MD 731' ND, INC = 12.62 DEG, AZ = 218.15 DEG. Use Halliburton Gyro surve .Crew Chan e 18:00 00:00 6.00 801 1,243 SURFA DRILL DDRL P Directional drill 16" Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 801' - 1243' MD (442') ND = 1215'. Total hrs on bit= 10.14 HRS, Jar HRS = 10.14 hrs, ADT = 3.81 HRS, ART 1.00 HRS, AST 2.81 HRS, WOB 25-30K, 50 RPM, Motor RPM - 148, 570 GPM's @ 1750 psi on bottom and 1550 psi off bottom. Torque = 4K ft-Ibs on botttom and 2K ft-Ibs off bottom. P/U = 125K, S/O = 120K, ROT WT= 120K .AVG Gas observed = 30 Units. Mud Wt = 9.1 PPG, Visc = 300 Survey @ 1228.85' MD 1202.23' ND, INC = 25.03 DEG, AZ = 191.05 DEG. Use Halliburton G ro surve . 11/20/2006 00:00 06:00 6.00 1,243 1,752 SURFA DRILL DDRL P Directional drill 16" Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 1243' - 1752' MD (509 ') ND = 1617'. Total hrs on bit= 14.41 HRS, Jar HRS = 14.41 hrs, ADT = 4.27 HRS, ART 1.04 HRS, AST 3.23 HRS, WOB -30K, 50 RPM, Motor RPM - 156, 600 GPM's @ 2150 psi on bottom and 1700 psi off bottom. Torque = 5-7K ft-Ibs on botttom and 2-3K ft-Ibs off bottom. P/U = 130K, S/O = 120K, ROT WT= 128K .AVG Gas observed = 78 Units. Mud Wt = 9.2 PPG, Visc = 300 Survey @ 1704.86' MD 1587.87' ND, INC = 45.67 DEG, AZ = 181.69 DEG. Use Halliburton Gyro survey. RD Gyro @ 1400' MD. Crew Chan e ~ ~ F~~ca~, ~ cif ~~a • Time Logs Date From To Dur S. De tp h E. De th Phase Code Subcode T__ COM _ 11/20/2006 06:00 10:00 .4.00 1,752 2,132 SURFA DR1LL DDRL P Directional drill 16" Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f! 1752' - 2132' MD (380') TVD = 1834'. Total hrs on bit= 16.85 HRS, Jar HRS = 16.85 hrs, ADT = 2.44 HRS, ART .70 HRS, AST 1.74 HRS, WOB 25-30K, 50 RPM, Motor RPM - 179, 690 GPM's @ 2580 psi on bottom and 2450 psi off bottom. Torque = 5-6K ft-Ibs on botttom and 3-4K ft-Ibs off bottom. P/U = 140K, S/O = 125K, ROT WT= 131 K .AVG Gas observed = 24 Units. Mud Wt = 9.2 PPG, Visc = 300 Survey @ 2085.78' MD 1814.55' TVD, INC = 62.49 DEG, AZ = 175.78 DEG. 10:00 11:45 1.75 2,132 2,132 SURFA DRILL REAM NP Wash & ream from 2041' - 2132'. Observed an 8.18 Degree dogleg, reaming it out to a 6.19 deg dogleg as per DD@ 690 GPM's @ 2380 psi off bottom. Torque = 2-3K ft-Ibs on botttom and 3-4K ft-Ibs off bottom. P/U = 140K, S/O = 125K, ROT WT= 131 K 11:45 12:00 0.25 2,132 2,180 SURFA DRILL DDRL P Directional drill 16" Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 2132' - 2180' MD (48') TVD = 1853'. Total hrs on bit= 17.10 HRS, Jar HRS = 17.10 hrs, ADT = .24 HRS, ART .24 HRS, AST 0 HRS, WOB 25-30K, 50 RPM, Motor RPM - 179, 690 GPM's @ 2500 psi on bottom and 2300 psi off bottom. Torque = 5-6K ft-Ibs on botttom and 3-4K ft-Ibs off bottom. P/U = 138K, S/O = 125K, ROT WT= 131 K .AVG Gas observed = 24 Units. Mud Wt = 9.2 PPG, Visc = 300 Survey @ 2180.15' MD 1855.58' TVD, INC = 65.96 DEG, AZ = 175.41 DEG. 12:00 16:15 4.25 2,180 2,572 SURFA DRILL DDRL P Directional drill 16"Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f! 2180' - 2572' MD (392') TVD = 1963'. Total hrs on bit= 19.88 HRS, Jar HRS = 19.88 hrs, ADT = 2.77 HRS, ART .87 HRS, AST 1.90 HRS, WOB 25-30K, 50 RPM, Motor RPM - 179, 690 GPM's @ 2500 psi on bottom and 2300 psi off bottom. Torque = 5-6K ft-Ibs on botttom and 3-4K ft-Ibs off bottom. P/U = 138K, S/O = 125K, ROT WT= 132K .AVG Gas observed = 24 Units. Mud Wt = 9.2 PPG, Visc = 300 Survey @ 2562.02' MD 1962.40' TVD, INC = 77.65 DEG, AZ = 165.14 DEG. • Time Logs i Date From To Dur S De th E. De th _ Phase Code Subcode T COM __ _ _ _ 11/20/2006 16:15 17:00 0.75 2,572 2,572 SURFA DRILL .CIRC NP Circulate & condition hole while catching up in Rockwasher. Rockwasher & tanks at full capacity. Called for extra Super Suckers to get ahead of cuttin s in tanks. 17:00 18:00 1.00 2,572 2,659 SURFA DRILL DDRL P Directional drill 16"Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 2572' - 2659' MD (87') TVD = 1982'. Total hrs on bit= 20.47 HRS, Jar HRS = 20.47 hrs, ADT = .59 HRS, ART .30 HRS, AST .29 HRS, WOB 25-30K, 50 RPM, Motor RPM - 179, 690 GPM's @ 2500 psi on bottom and 2300 psi off bottom. Torque = 5-6K ft-Ibs on botttom and 3-4K ft-Ibs off bottom. P/U = 138K, S/O = 125K, ROT WT= 132K .AVG Gas observed = 24 Units. Mud Wt = 9.2 PPG, Visc = 300 Survey @ 2656.89' MD 1982.35' TVD, INC = 78.08 DEG, AZ = 161.08 DEG. Crew Chan e 18:00 21:15 3.25 2,659 2,859 SURFA DRILL DDRL P Directional drill 16"Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 2659' - 2859' MD (200') TVD = 2030'. Total hrs on bit= 22.69 HRS, Jar HRS = 22.69 hrs, ADT = 2.22 HRS, ART .78 HRS, AST 1.44 HRS, WOB 25-30K, 50 RPM, Motor RPM - 175, 675 GPM's @ 2500 psi on bottom and 2300 psi off bottom. Torque = 6-7K ft-Ibs on botttom and 5-6K ft-Ibs off bottom. P/U = 135K, S/O = 110K, ROT WT= 125K .AVG Gas observed = 42 Units. Mud Wt = 9.2 PPG, Visc = 280 Survey @ 2847.52' MD 2026.49' TVD, INC = 74.33 DEG, AZ = 155.61 DEG. 21:15 21:45 0.50 2,859 2,859 SURFA DRILL CIRC P Circulate & condition hole while catching up in Rockwasher. Rockwasher & tanks at full capacity. Hole unloading. Continue working mud to allow visc to dro .Goal is 200 Visc. ~® ~® -- 3 ~'aq~; fi u~ ~_~ _.~ • Time Logs Date From To Dur S G`e th E. De th Phase Code Subcode _ T _ _ COM 11/20l2006 21:45 00:00 2.25 2,859 2,996 SURFA DRILL DDRL -_ NP - Directional drill 16" Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 2859' - 2996' MD (137') TVD = 2064'. Total hrs on bit= 24.13 HRS, Jar HRS = 24.13 hrs, ADT = 1.44 HRS, ART 1.09 HRS, AST .35 HRS, WOB 25-30K, 50 RPM, Motor RPM - 175, 675 GPM's @ 2500 psi on bottom and 2300 psi off bottom. Torque = 6-7K ft-Ibs on botttom and 5-6K ft-Ibs off bottom. P/U = 135K, S/O = 110K, ROT WT= 125K . AVG Gas observed = 48 Units. Mud Wt = 9.2 PPG, Visc = 280 Survey @ 2942.22' MD 2051.11' TVD, INC = 75.53 DEG, AZ = 155.39 DEG. 11/21/2006 00:00 06:00 6.00 2,996 3,415 SURFA DRILL DDRL P Directional drill 16"Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 2996' - 3415 MD 419 ') TVD = 2170'. Total hrs on bit= 27.65 HRS, Jar HRS = 27.65 hrs, ADT = 3.52 HRS, ART 2.29 HRS, AST 1.23 HRS, WOB 15-25K, 50 RPM, Motor RPM - 188-130, 725-500 GPM's @ 2650-1580 psi on bottom and 1490-2550 psi off bottom. Torque = 8-12K ft-Ibs on botttom and 5-8K ft-Ibs off bottom. P/U = 140-152K, S/O = 110-105K, ROT WT= 122-128K . Mud Wt = 9.5 PPG, Visc = 240 06:00 08:00 2.00 3,415 3,514 SURFA DRILL DDRL P Directional drill 16" Surface hole w/ 8" SperryDrill 4/5 lobe-5.3 stage mtr w/ 1.83 deg bend f/ 3415' - 3514' MD 99 ') TVD = 2198'. Total hrs on bit= 28.92 HRS, Jar HRS = 28.92 hrs, ADT = 1.27 HRS, ART 1.03 HRS, AST .24 HRS, WOB 15-25K, 50 RPM, Motor RPM - 157, 605 GPM's @ 2200 psi on bottom and 2090 psi off bottom. Torque = 9-10K ft-Ibs on botttom and 7-8K ft-Ibs off bottom. P/U = 152K, S/O = 100K, ROT WT= 128K . Mud Wt = 9.5 PPG, Visc = 240 08:00 09:00 1.00 3,514 2,170 SURFA DRILL REAM P Backream out of hole f/ 3514' to 2170'. Pumping 800 gpm w/ 3100 psi. Rotate 50 r m w/ 7-8k ft Ib for ue. 09:00 10:00 1.00 2,170 3,514 SURFA RIGMN RGRP T Repair shaker while RIH and tag bottom 3514'. 10:00 14:30 4.50 3,514 803 SURFA DRILL REAM P POOH, backreaming every other stand f/ 3514' to 803'. Pumping 600 gpm w/ 2200 psi. Rotate 60 rpm w/ 7-8k ft Ib .tor ue. Pullin 45 ft/min. 14:30 14:45 0.25 803 803 SURFA DRILL OTHR P Blow down top drive. 14:45 15:00 0.25 803 803 SURFA DRILL OWFF P Monitor well. static. ~mmm l~ac}~ ri Szi • Time Lo s _ __ __ Date From To Dur S. De th E. De th Phase Code Subcode T COM - _ - -- --- 11/21/2006 15:00 17:30 2.50 803 0 SURFA DRILL PULD P Rack back 7 stands of 5" HWDP (includes jars). Rack back stand of flex drill collars. UD MWD and motor. Break and grade bit (3-2-FC-M-E-1/16-ER-TD . 17:30 18:15 0.75 0 0 SURFA DRILL OTHR P Clear and clean rig floor. 18:15 18:45 0.50 0 0 SURFA RIGMN SVRG P Service drawworks and blocks. 18:45 20:45 2.00 0 0 SURFA CASIN( RURD P Rig up casing equipment. Remove bails. PU hydraulic lines f/ tongs. Install Frank's fillup tool. PU bails and PU sling. MU elevators and install spiders w/snub line. Double check i e shed f/ runnin order. 20:45 21:15 0.50 0 0 SURFA CASIN( RURD P Inspect stabbing board and rig up to run latform w/ to er. 21:15 21:45 0.50 0 0 SURFA CASINO SFTY P PJSM on running 13-3/8" casing w/ crew. GBR casing crew, MI mud engineer, tourpusher and company man. 21:45 00:00 2.25 0 420 SURFA CASIN( RNCS P Run 13-3/8" 68 ppf L-80 BTC casing: Weatherford model 303 sure seal FS on jt #1, baker locked jt #2, Weatherford model 402 float collar, jt #3, jt # 4 thru #10. Up to pin end of jt #4 is baker locked. Centralizers on stop 5' above shoe and 5' above float collar. Stops in center of first 10 joints w/ centralizer over stop. Centralizers over each collar. 11/22/2006 00:00 00:45 0.75 420 460 SURFA CASIN( CIRC NP Circ @ 6bpm w/ 200 psi thru Frank's fillup tool, washing to get joint # 11 in the hole f/ 420' to 460'. No down wt. 00:45 02:30 1.75 460 1,042 SURFA CASIN( RNCS P Continue to MU/RIH w/ 13-3/8" casing f/ 460' to 1042' (joint # 25 plus 4' on # 26). No down wt @ 1042'. Jts # 11-20 have a centralizer on the collars. 02:30 03:15 0.75 1,042 1,080 SURFA CASIN< CIRC NP Using Frank's fillup tool to Circ joint # 26 in hole. Pum in 6 b m w/ 230 si. 03:15 03:45 0.50 1,080 1,170 SURFA CASIN( RNCS P Continue MU/RIH w/ 13-3/8" casing f/ 1080' to 1170' Jt # 28 in the hole). 03:45 04:00 0.25 1,170 1,210 SURFA CASIN( CIRC NP Using Frank's fillup tool to circjoint# 29 in hole. Pum in 6 b m w/ 230 si. 04:00 04:45 0.75 1,210 1,584 SURFA CASIN( RNCS P Continue MU/RIH w/ 13-3/8" casing f/ 1210' to 1584' Jt # 38 in the hole . 04:45 05:15 0.50 1,584 1,580 SURFA CASIN( CIRC NP Using Frank's fillup tool to circjoint # 39 in hole. Pumping 6bpm w/ 450 psi. Circ 2 BU. 05:15 06:00 0.75 1,580 2,076 SURFA CASIN( RNCS P Continue MU/RIH w/ 13-3/8" casing f/ 1580' to 2076' Jt # 50 in the hole . 06:00 06:30 0.50 2,076 2,284 SURFA CASIN( RNCS P Continue MU/RIH w/ 13-3/8" casing f/ 2076' to 2284' Jt # 55 in the hole . 06:30 07:00 0.50 2,284 2,327 SURFA CASIN( CIRC NP Using Frank's fillup tool to circjoint # 56 in hole. Pumping 5-6 bpm w/ 560 si. .~ ~~~ cif ~G • • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 11/22/2006 07:00 10:00 3.00 2,327 3,456 SURFA CASIN( RNCS P Continue MU/RIH w/ 13-3/8" casing f/ 2327' to 3456' (Jt # 83 in the hole). Note: Jt # 81 has a centralizer on the collar. A total of 31 centralizers and 11 sto s were run. 10:00 10:15 0.25 3,456 3,456 SURFA CASIN< RNCS T MU Vetco Gray hanger w/ LH threads on top). Landing joint with wrong threads to make u to han er (RH . 10:15 10:45 0.50 3,456 3,456 SURFA CASIN( RNCS T Break out casing hanger. Lay down landing joint and hanger. MU 10' pup to circulate. 10:45 12:15 1.50 3,456 3,456 SURFA CASIN( CIRC P Break circulation w/ Frank's fillup tool. Circ and recip pipe @ 3456', while waiting on right landing joint (with LH threads). Circ @ 5 bpm w/ 270 psi. Pumped 325 bbls, a little over a bottom's u . 12:15 12:45 0.50 3,456 3,456 SURFA CASIN( RNCS T Break off 10' pup joint and lay down. Break and lay down Frank's fillup tool. Blow down to drive. 12:45 13:15 0.50 3,456 3,501 SURFA CASIN( RNCS P MU Vetco/Gray 13-3/8" hanger and landing joint. RIH f/ 3456' to 3501' and land on load shoulder. PU wt 275k, SO wt 135k. Blocks 70k. 13:15 14:00 0.75 3,501 3,501 SURFA CEME~ RURD P RU Dowell cement head and lines. 14:00 15:45 1.75 3,501 3,501 SURFA CEME~ CIRC P Break circulation. Reciprocate pipe 20' stroke f/ 3481' to 3501'. Circulate @ 6 bpm w/ 250 psi, increase to 7 bpm @ 1500 hrs w/ 290 si. 15:45 16:00 0.25 3,501 3,501 SURFA CEME~ SFTY P PJSM on cementing 13-3/8" casing. Continue to circ. 16:00 16:30 0.50 3,501 3,501 SURFA CEME~ CIRC P Continue to circulate and reciprocate pipe 20'. Circ 7 bpm w/ 220 psi. Total of 968 bbls pumped. Final mud properties prior to cementing: Weight 9.5 ppg, vis 45, PV/YP= 16/16, gels: 6/15/18, FI 8. 16:30 17:00 0.50 3,501 3,501 SURFA CEMEf~ OTHR P Dowell pump 10 bbls CW 100, test lines to 3000 psi, pump 40 bbls CW100, pump 50 bbls Mud push w/ red dye (10.5 ppg), drop bottom plug. Pipe was reciprocated f/ 3481' to 3501'. 17:00 18:30 1.50 3,501 3,501 SURFA CEME~ OTHR P Dowell mix and pump 552 bbls (690 sx) lead cement (ASlite) @ 10.66-10.7 ppg. Pumping @ 6.4 bpm w/ 243 psi. Pipe was reciprocated f/ 3481' to 3501' until cemnt was @ the shoe and then landed due to pipe becoming extremely difficult to go down (Barely of i e back down on han er . 18:30 19:00 0.50 3,501 3,051 SURFA CEME~ OTHR P Dowell mix and pump 98 bbls (220 sx) tail cement (DeepCrete) (12 ppg) @ 4 bpm w! 500 psi. Drop top plug, dowel) pump 20 bbls water thru tub and turn over to ri for dis lacement. ~a~ ~; a~ __ __ CJ • Time Logs - - - - ___ Date From To Dur S. De th E._Depth Phase Code Subcode T COM _ 11/23/2006 15:30 20:45 5.25 0 0 SURFA WELCT BOPE P Test BOPE to 250 psi low and 3000 psi high. Hold each test for 5 min. Chart test. Test accumulator. Check gas monitors. Top pipe rams (3-1/2" x 6" variables) tested w/ 5". Lower pipe rams (9-5/8") tested. Witness of test waived by AOGCC inspector Lou Grimaldi. 20:45 21:15 0.50 0 0 SURFA WELCT OTHR P Pull test plug, laydown 9-5/8" test 'oint. 21:15 21:45 0.50 0 0 SURFA RIGMN SVRG P Lubricate rig. 21:45 22:00 0.25 0 0 SURFA WELCT OTHR P PU 5" testjoint. Install Vetco/Gray wear bushing. Wear bushing measures 59 3/8" Ion , 12-3/8" ID. 22:00 22:15 0.25 0 0 SURFA WELCT OTHR P Blow down choke and kill lines. 22:15 22:45 0.50 0 0 SURFA DRILL OTHR P Clear and clean rig floor. 22:45 23:00 0.25 0 0 SURFA DRILL SFTY P PJSM on picking up 105 joints of Weatherford 5" S-135 drill pipe w/ Western Well Tools super sliders installed in middle of joint. Will be rabbitted to 2.90", torqued to 27000 ft Ibs for ue, stood back in derrrick. 23:00 00:00 1.00 0 0 SURFA DRILL PULD P Picking up 105 joints of Weatherford 5" S-135 drill pipe w/ Western Well Tools super sliders installed in middle of joint. Will be rabbitted to 2.90", torqued to 27000 ft Ibs torque, stood back in derrrick. Strap in derrick. 7 stands made up @ midnight. Note: Still cleanin mud its. 11/24/2006 00:00 02:45 2.75 0 0 SURFA DRILL PULD P Continue picking up 105 joints of Weatherford 5" S-135 drill pipe w/ Western Well Tools super sliders installed in middle of joint. Will be rabbitted to 2.90", torqued to 27000 ft Ibs torque, stood back in derrrick. Stra in derrick. 02:45 03:15 0.50 0 0 SURFA DRILL OTHR P Remove mouse hole from rotary table. Prep 5" slick dp in shed to be picked u . RU floot to PU/MU BHA #2. 03:15 05:00 1.75 0 60 SURFA DRILL PULD P PU/MU BHA #2. Make up Smith 12.25" 2 cone bit (ser # PD 5027), Sperry Drill 8" motor w/ 1.15 deg bend, nm 8" OD 12' pony collar, welded blade stabilizer (10.62" OD), nm crossover, Directional, Gamma/Res/PWD/HCIM, pulsar to 100'. Orient same w/ MWD. 05:00 05:45 0.75 60 60 SURFA DRILL OTHR P Upload MWD. 05:45 06:15 0.50 60 473 SURFA DRILL TRIP P Continue MU BHA #2. MU nm float sub, stand of 8" OD flex collar, x-o, (2) stands of 5" HWDP, jars and (2) joints of 5" HWDP to 473.49'. 3 i 6~ °w~ ~ ~i S 3 b~ ~~ I • ::.Time Logs __ -- -- Date From To Dur S. De th E De th Phase Code Subcod_e_ T COM _ 11!24/2006 06:15 09:30 3.25 473 2,378 SURFA DRILL PULD P PU/MU 60 joints of 90 total 5" Weatherford dp from pipe shed, RIH to 2378'. Rabbit i e to 2.90". 09:30 09:45 0.25 2,378 2,378 SURFA DRILL CIRC P Fill pipe @ 2378'. 09:45 11:15 1.50 2,378 3,328 SURFA DRILL PULD P Continue PU/MU 5" Weatherford dp from pipe shed (total of 90 jts PU f/ shed), RIH from 2378' to 3328'. Rabbit i e to 2.90". 11:15 11:30 0.25 3,328 3,328 SURFA DRILL OTHR P Lay down skate adapter for lay down machine on rig floor. Lay down thread protectors. Move 4 stands of 5" HWDP f/ ODS to drillers side of derrick. 11:30 11:45 0.25 3,328 3,413 SURFA DRILL TRIP P Make top drive connection on stand # 31. Fill pipe. Tag float collar @ 2413'. Rotate 50 rpm w/ 6-7 k ft Ib torque. Pumping 200 gpm. PU wt 135k, SO wt 105k, Rot wt 125k. 11:45 12:45 1.00 3,413 3,413 SURFA DRILL CIRC P Circulate bottoms up @ 400 gpm. Rotate 50 rpm w/ 9-10k ft Ib torque. Pum 647 bbls. 12:45 13:00 0.25 3,413 3,325 SURFA DRILL OTHR P Stand back stand # 31. Blow down top drive. 13:00 14:00 1.00 3,325 3,325 SURFA RIGMN RGRP T Remove shock pin f/ locking handling rin on to drive. 14:00 14:15 0.25 3,325 3,325 SURFA RIGMN SFTY P PJSM on cutting and slipping drilling line. 14:15 15:45 1.50 3,325 3,325 SURFA RIGMN SVRG P Slip and cut 68' of 1-3/8"drilling line. 15:45 16:15 0.50 3,325 3,325 SURFA RIGMN SVRG P Service rig, top drive and crown. 16:15 17:00 0.75 3,325 3,325 SURFA RIGMN RGRP T Install a new shock pin assembly for the handling ring on the Varco TDS8 to drive. 17:00 17:30 0.50 3,325 3,325 SURFA CASIN( OTHR P RU lines for casing test. 17:30 18:15 0.75 3,325 3,325 SURFA CASIN( DHEQ P Test casing to 3000 psi: Hold f/ 30 minutes. Chart test. 18:15 18:30 0.25 3,325 3,325 SURFA CASIN< OTHR P Bleed off pressure. Rig down lines. 18:30 19:45 1.25 3,325 3,501 SURFA CEME~ COCF P Make top drive connection. Drill float collar @ 3413' ,cement, FS @ 3501' (2196' TVD). PU wt 148k, SO wt 110k, Rot wt 125k. Pumping 540 gpm w/ 1050 psi. 80 rpm w/6k ft Ib torque. Motor r m 140. WOB 12k. 19:45 20:15 0.50 3,514 3,534 SURFA DRILL DRLG P Drill rat hole f/ 3501' to 3514' and 20' of new formation to 3534'. Pumping 540 gpm w/ 1050 psi. Rotating 80 rpm w/ 6k ft Ib torque. Motor rpm = 140. ADT .17 hrs. Jar hrs 29.09. 20:15 21:00 0.75 3,534 3,534 SURFA DRILL CIRC P Break off a stand, Circ and condition thick mud prior to displacement to new LSND mud. Rotate 50 rpm, work pipe f/ 3501' to 3423' (inside casing). Circ 566 bbls. ~- P~cte #2 csf C~ C~ Time Los Date From To D_ur - S. De th E Degth Phase Code Subcode T COM - - 11/24/2006 21:00 22:00 1.00 3,534 3,534 SURFA DRILL CIRC P Displace to 9.0 ppg new LSND mud. Displace mud in hole f/ 3515'. New mud weight is 9.0 ppg. Pump 600 bbls. Pumping 592 gpm w/ 1050 psi. Rotate 50 rpm w/ 7k ft Ib torque. Hole volume is 500 bbls. 22:00 22:15 0.25 3,534 3,534 SURFA DRILL OTHR P Break off a single. Blow down top drive. 22:15 22:30 0.25 3,534 3,534 SURFA CEME~ LOT P RU to Perform LOT w/drill bit @ 3484'. Isolate pump #2. Circ through kill line rior to test. 22:30 23:45 1.25 3,534 3,534 SURFA CEMEP LOT P Perform LOT w/drill bit @ 3484'. 13-3/8" casing shoe @ 3501' (2196' TVD). 13' of open hole was cleaned out to 3514' (2198' TVD). New hole (12-1/4") was drilled to 3534'. New LSND MW is 9.0 ppg. LOT w/ 540 psi =EMWof13.7 23:45 00:00 0.25 3,534 3,534 SURFA CEME~ LOT P RD equipment and lines f/ LOT. Blow down choke and kill lines. 11/25/2006 00:00 06:00 6.00 3,534 4,258 INTRM1 DRILL DDRL P PU/MU single. Make top drive connection on stand #33. Drill 12-1/4" intermediate hole w/ BHA #2 : Smith Two cone insert, 8" SperryDrill lobe 4/5-5.3 stage motor w/ 1.15 deg bend, nm pony collar welded blade stab (10.62" OD), x-o, DIR/Gamma/Res/PWD/HCIM/Pulsar, float sub, nm x-o, (3) nm flex drill collar, x-o, (6) 5" HWDP, jars, (2) 5" HWDP= total of 473.49'. Drilling 12-1/4" intermediate f/ 3534' to 4258' (724') (2407' TVD) Bit hours= 3.98, Jar (#15061147) hours= 32.90, ART= 2.13 hrs, AST = 1.68 hrs, WOB= 10-30k, 100 rpm, mtr rpm = 168-201, 645-775 gpm @ 1250- 1700 psi on bottom and 1050-1610 psi off bottom. Torque = 8-11 k ft-Ibs on botttom and 4-8k ft-Ibs off bottom. ECD= 9.28 -9.7 ppg. Max gas 80 units. P!U = 145-155 k, S/O = 125-110 k, Rot= 100-130 k w/ pumps off. __~.__~_ _ _.~P~g~ -'{ ~t s Time Logs - __ Date From To Dur S. De th E De nth Phase Code Subcode T COM 11/25/2006 06:00 12:00 6.00 4,258 5,020 INTRM1 DRILL DDRL P Drilling 12-1/4" intermediate f/ 4258' to 5020' (762') (2564' TVD) Bit hours= 7.39, Jar (#15061147) hours= 37.32, ART= 1.97 hrs, AST = 1.44 hrs, WOB= 5-25k, 100 rpm, mtr rpm = 201-182, 775-703 gpm @ 1870- 1570 psi on bottom and 1610 -1550 psi off bottom. Torque = 7-11k ft-Ibs on botttom and 5-10k ft-Ibs off bottom. ECD= 9.7-9.79 ppg. Av gas 14 units. P/U = 150-180k, S/O = 110-95k, Rot= 130-135 k w/ pumps off. 12:00 13:30 1.50 5,020 5,117 INTRM1 DRILL DDRL P Drilling 12-1/4" intermediate f/ 5020' to 5117' (97') (2588' TVD) Bit hours= 8.40, Jar (#15061147) hours= 37.32, ART= .38 hrs, AST = .63 hrs, WOB= 20-30k, 100 rpm, mtr rpm = 176, 680 gpm @ 1800 psi on bottom and 1650 psi off bottom. Torque = 11-15k ft-Ibs on botttom and 8-12k ft-Ibs off bottom. ECD= 10.08 ppg. Av gas 17 units. P/U = 185k, S/O = 100k, Rot= 130k w/ pumps off. Pumped a 40 bbl Hi vis (200+), weighted (10.9 ppg) sweep @ 5064'. Bi increase in cuttin s. 13:30 16:00 2.50 5,117 5,117 INTRM1 DRILL CIRC P Circulate and condition hole after clearing packed off possum belly on shakers. Initial pumping @ 2.5 bpm w/ 190 psi, 40 rpm w/ 6-7k ft Ibs torque until able to pump @ full rate and shakers handle OK. 16:00 18:00 2.00 5,117 5,324 INTRM1 DRILL DDRL P Drilling 12-1/4" intermediate f/ 5117' to 5324' (207') (2640' TVD) Bit hours= 9.81, Jar (#15061147) hours= 38.73, ART= .86 hrs, AST = .55 hrs, WOB= 20-30k, 100 rpm, mtr rpm = 176-185, 680-710 gpm @ 1920-1600 psi on bottom and 1860-1550 psi off bottom. Torque = 8-15k ft-Ibs on botttom and 5-12k ft-Ibs off bottom. ECD= 10.08-9.54 ppg. Av gas 18 units. P/U = 185-190k, S/O = 100-90k, Rot= 130-125k w/pumps off. Pumped a 30 bbl Hi vis (200+), weighted (10.9 ppg) sweep @ 5230'. Sli ht increase in cuttin s. ~_ e ,f ~w~ ~'w Et }~ BFS ~. l_....~_.._._._.,....... l~J ~J Time Logs Date From To _ Dur S De th E_ De th Phase Code Subcode T _ COM 11/25/2006 18:00 00:00 6.00 5,324 5,701 INTRM1 DRILL DDRL P Drilling 12-1/4" intermediate f/ 5324' to 5701' (377') (2728' TVD) Bit hours= 13.34, Jar (#15061147) hours= 42.26, ART= .73 hrs, AST = 2.80 hrs, WOB= 10-30k, 100 rpm, mtr rpm = 176-185, 675-700 gpm @ 1920-1600 psi on bottom and 1860-1550 psi off bottom. Torque = 8-15k ft-Ibs on botttom and 5-12k ft-Ibs off bottom. ECD= 10.08-9.54 ppg. Av gas 18 units. P/U = 185-190k, S/O = 100-90k, Rot= 130-125k w/ um s off. 11/26/2006 00:00 05:15 5.25 5,701 6,085 INTRM1 DRILL DDRL P Directional drill 12-1/4" intermediate hole w/ BHA #2 : Smith Two cone insert, 8" SperryDrill lobe 4/5-5.3 stage motor w/ 1.15 deg bend, nm pony collar welded blade stab (10.62" OD), x-o, DIR/Gamma/Res/PWD/HCIM/Pulsar, float sub, nm x-o, (3) nm flex drill collar, x-o, (6) 5" HWDP, jars, (2) 5" HWDP= total of 473.49'. Directional drilling 12-1/4" intermediate f/ 5701' to 6085' (384') (2824' TVD) Bit hours= 16.34, Jar (#15061147) hours= 45.26, ART= 1.28 hrs, AST = 1.72 hrs, W06= 6-30k, 100 rpm, mtr rpm = 175, 673 gpm @ 1730-1840 psi on bottom and 1650-1780 psi off bottom. Torque = 11-16k ft-Ibs on botttom and 10-14k ft-Ibs off bottom. ECD= 9.53-9.63 ppg. Max gas 68 units. P/U = 200-190k, S/O = 88-95k, Rot= 135-138k w/ pumps off. Pumped a 30 bbls Hi vis (290) hi weight (10.5 ppg) sweep while drilling @ 5700'. No significant increase in cuttin s. 05:15 05:45 0.50 6,085 5,990 INTRM1 DRILL TRIP P Survey @ 6085'. Backream f/ 6085' to 5990'. Stood back stand # 58. 05:45 07:30 1.75 5,990 5,990 INTRM1 DRILL CIRC P Circulate and work pipe f/ 5990'to 5890'. Pumping 850 gpm w/ 2350 psi. Rotate @ 100 rpm w/ 9-12k ft Ib torque. Pump 45 bbls hi vis (300+) high weight (10.5 ppg) sweep. Follow sweep with 1969 bbls pumped to clean hole prior to a open hole leak off test. Sweep appeared to help clean hole alon w! increase of flow rate. 07:30 08:00 0.50 5,990 5,990 INTRMI DRILL LOT P PJSM. Perform open hole LOT. MW 9.1 ppg, shoe @ 3501' (2196' TVD), open hole to 6085' (2824'). Leak off @ 230 psi = 11.1 ppg EMW. Pumped 3 bbls after it appeared to leak off. Bleed off ressure. C_~ Time Logs - -- - - -_ Date From To Dur S. De th E_ Depth Phase Code__Subcode T_ COM 11/26/2006 08:00 08:30 0.50 5,990 6,085 INTRM1 DRILL TRIP P Blow down kill line. Make stand up and ream f/ 5990' to 6085'. 08:30 12:00 3.50 6,085 6,452 INTRM1 DRILL DDRL P Directionai drilling 12-1/4" intermediate f/ 6085' to 6452' (367') (2824' TVD) Bit hours= 17.98, Jar (#15061147) hours= 46.90, ART= 1.64 hrs, AST = 0 hrs, W06= 10-30k, 80-120 rpm, mtr rpm = 195-221, 750-850 gpm @ 2070-2520 psi on bottom and 2000-2525 psi off bottom. Torque = 11-17k ft-Ibs on botttom and 8-16k ft-Ibs off bottom. ECD= 9.61-9.81 ppg. P/U = 181-90k, S/O = 100-95k, Rot= 135-140k w/ um s off. 12:00 18:00 6.00 6,452 6,917 INTRM1 DRILL DDRL P Directional drilling 12-1/4" intermediate f/ 6452' to 6917' (465') (3002' TVD) Bit hours= 21.52, Jar (#15061147) hours= 50.44, ART= 1.86 hrs, AST = 1.68 hrs, W06= 10-25k, 120-140 rpm, mtr rpm = 221-208, 850-800 gpm @ 2550-2400 psi on bottom and 2550-2340 psi off bottom. Torque = 11-12k ft-Ibs on botttom and 8-15k ft-Ibs off bottom. ECD= 9.77-9.91 ppg. Avg gas = 35 units. P/U = 190-195k, S/O = 100-90k, Rot= 140-142k w/ um s off. 18:00 00:00 6.00 6,917 7,513 INTRM1 DRILL DDRL P Directional drilling 12-1/4" intermediate f/ 6917' to 7513' (596') (3149.87' TVD) Bit hours= 24.74, Jar (#15061147) hours= 53.66, ART= 2.0 hrs, AST = 1.22 hrs, WOB= 5-30k, 120-140 rpm, mtr rpm = 221-208, 880-900 gpm @ 2870-3200 psi on bottom and 2750-3000 psi off bottom. Torque = 12-15k ft-Ibs on botttom and 11-14k ft-Ibs off bottom. ECD= 10.07-10.2 ppg. Max gas = 110 units. P/U = 197-185k, S/O = 100-112k, Rot= 140-145k w/ pumps off. Pumped a 30 bbls Hi Vis (300+) weighted (10.5 ppg) sweep while drillin 6943'. ~ ~ ~ _. ~e~_ .e® ~ r~s~ ~6 0f ~~a s Time Logs Date From To -__. Dur S. De th E. De th Phase Code Subcode T _--_ COM - 11/27/2006 00:00 - 06:00 -- - 6.00 7,513 8,083 INTRM1 DRILL DDRL P Directional drilling 12-1/4" intermediate f/ 7513' to 8083' (570') (3301' TVD) Bit hours= 27.98, Jar (#15061147) hours= 56.92, ART= 1.72 hrs, AST = 1.54 hrs, WO6= 5-30k, 120 rpm,. mtr rpm = 234-195, 900-750 gpm @ 3200-2925 psi on bottom and 3000-2200 psi off bottom. Torque = 12-15k ft-Ibs on botttom and 11-14k ft-Ibs off bottom. ECD= 10.2 ppg. Max gas = 2000 units. P/U = 188-192k, S/O = 112-115k, Rot= 145-148k w/ pumps off. Pumped a 40 bbis Hi vis (275) high weight (10.5 ppg) sweep while drilling 8083'. 06:00 12:00 6.00 8,083 8,670 INTRM1 DRILL DDRL P Directional drilling 12-1/4" intermediate f/ 8083' to 8670' (587') (3439' TVD) Bit hours= 30.97, Jar (#15061147) hours= 59.89, ART= 1.93 hrs, AST = 1.03 hrs, WO6= 14-30k, 120 rpm, mtr rpm = 193-228, 745-880 gpm @ 2425-3110 psi on bottom and 2240-2700 psi off bottom. Torque = 12-15k ft-Ibs on botttom and 11-14k ft-Ibs off bottom. ECD= 9.79-10.24 ppg. Avg gas = 35 units. P/U = 192-205k, S/O = 110-118k, Rot= 145-140k w/ pumps off. 12:00 15:45 3.75 8,670 8,844 INTRM1 DRILL DDRL P Directional drilling 12-1/4" intermediate f/ 8670' to 8844' (174') (3475' TVD) Bit hours= 33.3, Jar (#15061147) hours= 62.22, ART= .52 hrs, AST = 1.81 hrs, WO6= 20-30k, 120 rpm, mtr rpm = 199-195, 767-750 gpm @ 2560-2360 psi on bottom and 2260-2250 psi off bottom. Torque = 12-15k ft-Ibs on botttom and 12-13k ft-Ibs off bottom. ECD= 10.22-10.16 ppg. Avg gas = 30 units. P/U = 210-205k, S/O = 112k, Rot= 138-k w/ um s off. 15:45 17:30 1.75 8,844 8,844 INTRM1 DRILL OTHR NP Clean screens on both pumps. Mode switch MWD, trying to get better detection. 17:30 18:00 0.50 8,844 8,858 INTRM1 DRILL DDRL P Directional drilling 12-1/4" intermediate f/ 8844' to 8858' (14') (3477' TVD) Bit hours= 33.58, Jar (#15061147) hours= 62.50, ART= .28 hrs, AST = hrs, WO6= 20-25k, 120 rpm, mtr rpm = 195, 750 gpm @ 2360 psi on bottom and 2260 psi off bottom. Torque = 10-15k ft-Ibs on botttom and 12-13k ft-Ibs off bottom. ECD= 10.16 ppg. Avg gas = 30 units. P/U = 205k, S/O = 112k, Rot= 137-k w/ um s off. ~~~ ~~ ~ ~d ~__ ;`~~~ 17 s~f ~u • Time Logs ~~ -- _ - -- -. Date From To Dur_ S De th E. De th Phase Code Subcode T COM _ 11/27!2006 18:00 18:45 0.75 8,858 8,657 INTRM1 DRILL TRIP __ T Monitor well, static. Blow down top drive. POOH on elevators f/ 8858' to 8657'. Monitoring hole fill on trip tank. PU wt 205k, SO wt 110k, Rot wt 135k. 18:45 19:15 0.50 8,657 8,850 INTRM1 DRILL TRIP T Trip in hole f/ 8657' to 8850'. PU wt 205k, SO wt 110k, Rot wt 135k. 19:15 19:30 0.25 8,850 8,858 INTRM1 DRILL CIRC T Make up top drive. Establish circulation. Pumping 750 gpm w/ 2360 psi. Rotate 120 rpm w/ 12-13k ft Ib torque. Trouble shooting downhole problem (torquing up and pressuring u . 19:30 20:30 1.00 8,858 8,182 INTRM1 DRILL TRIP T Monitor well, static. Blow down top drive. POOH on elevators f/ 8858' to 8182'. Monitoring hole via trip tank. PU wt 205k, SO wt 110k. 20:30 21:15 0.75 8,182 7,706 INTRM1 DRILL REAM T Backream out of hole f/ 8182' to 7706'. Pumping 800 gpm w/ 2550 psi. Rotate 80 r m w/ 10-18 ft Ib for ue. 21:15 21:30 0.25 7,706 7,420 INTRM1 DRILL .TRIP T Monitor well, static. Blow down top drive. POOH on elevators f/ 7706' to 7420'. PU wt 205k, SO wt 110k, Rot wt 135k. 21:30 23:00 1.50 7,420 6,755 INTRM1 DRILL REAM T Backream out of hole f/ 7420' to 6755'. Pumping 875 gpm w/ 2550 psi. Rotate 80 rpm w/ 10-18 ft Ib torque. PU wt 210-225k, SO wt 100k, Rot wt 120k. 23:00 00:00 1.00 6,755 6,183 INTRM1 DRILL TRIP T Monitor well, static. Blow down top drive. POOH on elevators f/ 6755' to 6183'. Monitor well using trip tank. PU wt 190k, SO wt 100k. 11/28/2006 00:00 01:00 1.00 6,183 5,517 INTRM1 DRILL TRIP T POOH on elevators f/ 6183' to 5517'. Monitor well using trip tank. PU wt 200k, SO wt 100k. 01:00 05:15 4.25 5,517 3,423 INTRM1 DRILL REAM T Backream out of hole f/ 5517' to 3423'. Pumping 850 gpm w/ 2200 psi. Rotate 80 rpm w/ 10-14 ft Ib torque. PU wt 210-160k, SO wt 100k, Rot wt 120k. 05:15 06:00 0.75 3,423 3,423 INTRM1 DRILL CIRC T Circ 1-1/2 BU (680 bbls). Recip f/ 3423' to 3328'. Pumping 850 gpm w/ 2150 psi. 50 rpm w/ 6k ft Ib torque. Lots of clay balls circulated out. PU Sperry Sun MWD short tools and put in i e shed. 06:00 06:15 0.25 3,423 3,423 INTRM1 DRILL OWFF T Monitor well, Static. 06:15 06:30 0.25 3,423 3,423 INTRM1 DRILL CIRC T Pump 30 bbl dry job. Blow down top drive. 06:30 08:15 1.75 3,423 470 INTRM1 DRILL TRIP T POOH on elevators f/ 3423' to 470'. 08:15 08:30 0.25 470 470 INTRM1 DRILL OWFF T Monitor well @ BHA (470'). 08:30 09:15 0.75 470 100 INTRM1 DRILL TRIP T Continue POOH, stand back 5" HWDP and jars, stand back 8" flex collars. _~ _ r ~g~: '1 of ~G ~ C~ J L I Time ~s Date From To___ Dur S~Depth E. De th Phase _ Code Subco_de T COM _ 11/28/2006 09:15 09:30 0.25 100 0 INTRM1 DRILL TRIP T POOH w/ Sperry MWD and mtr. Pull bit above floor. Missing one of (2) cones. Break off bit. 09:30 10:30 1.00 0 0 INTRM1 DRILL OTHR T Download Sperry Sun MWD. 10:30 11:45 1.25 0 0 INTRM1 DRILL PULD T UD BHA #2 to pipe shed. 11:45 12:15 0.50 0 0 INTRM1 DRILL OTHR T Clear and clean rig floor. Service top drive. 12:15 12:45 0.50 0 0 INTRM1 DRILL PULD T MU bit#3 (12-1/4" Hughes MXL-1, w/ (1) 13 and (3) 20's). Screw onto SperryDrill motor w/ 1.50 deg bend and 12" stabilizer. 12:45 13:00 0.25 0 0 INTRM1 DRILL SFTY T PJSM on picking up BHA # 3 f/ pipe shed. 13:00 13:30 0.50 0 0 INTRM1 DRILL PULD T PU/MU BHA #3. 13:30 14:00 0.50 0 90 INTRM1 DRILL OTHR T Orient motor to MWD. 14:00 14:30 0.50 90 90 INTRM1 DRILL OTHR T Upload MWD. MU float sub 14:30 15:00 0.50 90 462 INTRM1 DRILL TRIP T MU stand of 8" flex collar, then 3 stands of 5" HWDP includes jars to 462'. 15:00 16:15 1.25 462 2,370 INTRM1 DRILL TRIP T RIH w/ BHA #3 on 5" drill pipe. RIH 20 stands to 2370'. 16:15 16:45 0.50 2,370 2,370 INTRM1 DRILL TRIP T Fill pipe. Shallow test MWD @ 2370'. Pum 725 m w/ 1600 si. 16:45 17:15 0.50 2,370 3,400 INTRM1 DRILL TRIP T Blow down top drive. Trip in hole f/ 2370' to 3400'. 17:15 18:15 1.00 3,400 3,400 INTRM1 DRILL CIRC T Circulate bottom's up. Pumping 700 m w/ 2110 si. Pum 400 bbls. 18:15 20:00 1.75 3,400 4,740 INTRM1 DRILL TRIP T Blow down top drive. Trip in hole f/ 3400' to 4740' on elevators. PU wt 138k, SO wt 98k. 20:00 20:30 0.50 4,740 4,740 INTRM1 DRILL CIRC T Fill pipe @ 4740'. Blow down top drive. 20:30 21:00 0.50 4,740 5,025 INTRM1 DRILL TRIP T Trip in hole on elevators f/ 4740' to 5025'. PU wt 175k, SO wt 80k. 21:00 23:15 2.25 5,025 6,168 INTRM1 DRILL TRIP T Making top drive connection and washing in hole f/ 5025' to 5506' because of no down wt. Trip on elevators f/ 5506' to 5697', washing in hole f/ 5697' to 5982', trip in on elevators f/ 5982' to 6072', washing in hole f/ 6072' to 6168'. While pumping @ 3.75 bpm (158 gpm) w/ 400 psi. After washing down : PU wt 180k, SO wt 90k. _.~ ~~ ~.._ _.w P~~~~ ! aa~ ~„ ~~ C~ Time Lo s ~ -- - - - Date _ - From To Dur S. De th E. De th Phase Code Subcode T_ _COM _ _ 11/28/2006 23:15 00:00 0.75 6,168 6,168 INTRM1 DRILL CIRC T _ Circulate and reciprocate f/ 6168' to 6072'. Pumping on the up stroke. Pumping 800 gpm w/ 2350 psi. Rotate 80 rpm w/ 8-12k ft Ib torque. No rotation or pumping while slacking off to prevent sidetracking hole. Initial ECD was 10.55 ppg, final ECD after pumping 1-1 /2 BU 10.23 ppg. Circulated total of 1433 bbls (1-1/2 BU . 11/29/2006 00:00 00:15 0.25 6,168 6,072 INTRM1 DRILL CIRC T Circulate and reciprocate f/ 6168' to 6072'. Pumping on the upstroke. Pumping 800 gpm w/ 2350 psi. Rotate 80 rpm w/ 8-12k ft Ib torque. No rotation or pumping while slacking off to prevent sidetracking hole. Initial ECD was 10.55 ppg, final ECD after pumping 1-1 /2 BU 10.23 ppg. Circulated total of 1433 bbls (1-1/2 BU . 00:15 01:30 1.25 6,072 6,739 INTRM1 DRILL TRIP T Tripping in hole w/top drive f/ 6072' to 6739'. Circ 2.96 bpm w/ 400 psi while running in hole. PU wt 200k, So 90k after washin down. 01:30 02:30 1.00 6,739 7,596 INTRM1 DRILL TRIP T Trip in hole on elevators f/ 6739' to 7596'. PU wt 200k, So wt 90k. 02:30 03:45 1.25 7,596 7,691 INTRM1 DRILL CIRC T Tripping in hole w/ top drive f/ 7596' to 7691'. Circ 2.96 bpm w/ 400 psi while running in hole. Circ hole clean whlie picking up, pumping 800 gpm w/ 2400 psi, rotate 80 rpm w/ 11-12k ft Ib torque. No pumps or rotation on down stroke. PU wt 200k, SO wt 90k after washing down. Inital ECD's 10.28-10.0 . Pum ed total of 1443 bbls. 03:45 04:00 0.25 7,691 7,882 INTRM1 DRILL TRIP T Trip in hole on elevators f/ 7691' to 7882'. PU wt 200k, SO wt 90k. 04:00 05:00 1.00 7,882 8,646 INTRM1 DRILL TRIP T Tripping in hole w/top drive f/ 7882' to 8646': Circ 2.96 bpm w/ 400 psi while running in hole. PU wt 200k, SO wt 90k after washin down. 05:00 05:15 0.25 8,646 8,614 INTRM1 DRILL TRIP T POOH w/ a single, break off single, make up next stand to begin troughing for sidetrack. 05:15 07:15 2.00 8,614 8,700 INTRM1 STK KOST T Troughing f/ sidetrack. Troughing f/ 8614' to 8700'. Pumping 755 gpm w/ 2400 si. 07:15 09:45 2.50 8,700 8,858 INTRM1 DRILL DDRL T Drill 12-1/4" intermediate hole f/ 8700' to previous depth prior to sidetrack (8858', one cone of two cone bit in hole). ART .51 hrs, AST .96 hrs, jar hours 65.41, ECD's 9.99 09:45 12:00 2.25 8,858 9,043 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole f/ 8858' to 9043' (185') (3506' TVD): ART .63 hrs, AST .81 hrs, jar hours 65.41. ECD's 10.18 ~ ~ e ~~~ ~ j ~~~ ~~~ zit' • Time Logs Date From To Dur S Cie th E. Depth Phase Code Subcod_e T COM ____ 11/29/2006 12:00 18:00 6.00 9,043 9,370 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole f/ 9043' to 9370' (3557' TVD). ART 2.48 hrs, AST .99 hrs, jar hours 68.88. ECD's 10.04 18:00 22:15 4.25 9,370 9,745 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole f/ 9370' to 9745' (3592' TVD). ART .59 hrs, AST .79 hrs, jar hours 71.26. ECD's 10.1 22:15 00:00 1.75 9,745 9,596 INTRM1 DRILL CIRC P Pump 45 bbls of 10.5 ppg, 220 vis sweep in drill pipe, circ to near bit. Stand a stand back. Circulate while picking up @ 850 gpm/3100 psi. Stand a stand back eve hr. 11/30/2006 00:00 03:30 3.50 9,596 9,216 INTRM1 DRILL CIRC P Circulate. Rotating 80 rpm w/ 14-16k ft Ib torque. Pumping 850 gpm w/ 3100 psi. Pull and set back a stand every hr. 03:30 03:45 0.25 9,216 9,216 INTRM1 DRILL OWFF P Monitor well, OK. 03:45 04:15 0.50 9,216 8,927 INTRM1 DRILL TRIP P POOH on elevators with BHA #3 f/ 9216' to 8927'. Started swabbin . 04:15 04:30 0.25 8,927 9,216 INTRM1 DRILL TRIP P RIH to 9216'. 04:30 06:00 1.50 9,216 8,455 INTRM1 DRILL REAM P Backream out of hole f/ 9216' to 8455'. Rotating 80 rpm w/ 15-18 ft Ib torque. Pumping 850 gpm w/ 2900 psi. After backreaming: PU wt 220k, SO wt 100k, Rot wt 150k. Record PU and SO wt's eve 5 stands. 06:00 07:00 1.00 8,455 7,595 INTRM1 DRILL REAM P Backream out of hole f/ 8455' to 7595'. Rotating 80 rpm w/ 15-18 ft Ib torque. Pumping 850 gpm w/ 2900 psi. After backreaming: PU wt 220k, SO wt 100k, Rot wt 150k. Record PU and SO wt's eve 5 stands. 07:00 08:30 1.50 7,595 6,362 INTRM1 DRILL TRIP P Pull out of hole on elevators f/ 7595 to 6362. Record PU & SO wt's every 5 stands. Hole appears not clean. PU wt's runnin hi h. 08:30 14:30 6.00 6,362 3,501 INTRM1 DRILL REAM P Backream out of hole f/ 6362' to above shoe @ 3501". Rotating 80 rpm w/ 15-18 ft Ib torque. Pumping 850 gpm w/ 2900-2100 psi. After backreaming: Record PU and SO wt's every 5 stands. 14:30 15:45 1.25 3,501 3,412 INTRM1 DRILL CIRC P Pump 50 bbl hi vis(220), High weight (11.4 ppg), circ total of 1200 bbls. Pump Casing tube (3 drums LoTorq + 1 drum Steel lube). Rotate 80 rpm w/ 7-8k ft Ib torque. Pumping 850 gpm w/ 1950 si. 15:45 16:00 0.25 3,412 3,412 INTRM1 DRILL OWFF P Monitor well. Static. 16:00 16:30 0.50 3,412 3,412 INTRM1 DRILL CIRC P Pump 20 bbls dry job. Blow down top drive. 16:30 17:30 1.00 3,412 180 INTRM1 DRILL TRIP P POOH w/ BHA #3 from 3412' to 180'. _ ______ _ ~ _ ®s_ ~ Pag~2tta~~ ~ ~ Time Logs - -- _ _ _ - - Date From__ _To Dur S. De th__ E Depth Phase Code Subcode T _ COM _ _ 11/30/2006 17:30 19:00 1.50 180 90 INTRM1 DRILL PULD P Lay down Sperry Sun 8" Flex collars. 19:00 19:30 0.50 90 90 INTRM1 DRILL OTHR P Download Sperry Sun MWD 19:30 20:30 1.00 90 0 INTRM1 DRILL PULD P Lay down rest of BHA. 20:30 21:00 0.50 0 0 INTRM1 DRILL OTHR P Pull Vetco Gray 13-1/4" OD x 12-3/8" ID wear bushing 59-3/8" long. Clear and clean ri floor. 21:00 23:30 2.50 0 0 INTRM1 CASIN( RURD P Rig up to run 9-5/8" 40 ppf L-80 BTCM intermediate casin . 23:30 23:45 0.25 0 0 INTRMI CASIN( SFTY P Perform stabbing board inspection rior to runnin casin . 23:45 00:00 0.25 0 0 INTRM1 CASIN( RURD P Rigging up to run casing. 12/01/2006 00:00 00:30 0.50 0 0 INTRM1 CASIN( RURD P Rig up to run 9-5/8" 40 ppf L-80 BTC-m Casin . 00:30 01:00 0.50 0 0 INTRM1 CASIN( SFTY P PJSM w/ rig crew and GBR casing crew on running 9-5/8" intermediate casin er Ian. 01:00 07:15 6.25 0 3,497 INTRM1 CASIN( RNCS P PU/MU/RIH w/ 9-5/8" casing per plan to 2343'. Record PU and SO wt's eve 5 'ts. Monitor well on active its. 07:15 08:00 0.75 3,497 3,497 INTRM1 CASIN( CIRC P Circulate and condition mud @ 13-3/8" shoe. Bring LoDrag centralizers to the floor. Circ @ 6.5 bpm w/ 350 psi. Pum BU+ 210 bbls 08:00 10:30 2.50 3,497 6,000 INTRM1 CASIN( RNCS P Continue PU/MU/RIH w/ 9-5/8" casing per plan to 6000'. Record PU and SO wt's every 5 jts. Monitor well on active its. 10:30 11:30 1.00 6,000 6,000 INTRM1 CASIN( CIRC P Circulate and condition mud @ 6000'. Circ @ 6.5 bpm w/ 420 psi. Pump BU+ 300 bbls) 11:30 17:00 5.50 6,000 9,742 INTRM1 CASIN< RNCS P Continue PU/MU/RIH w/ 9-5/8" casing per plan to 9742'. Record PU and SO wt's every 5 jts. Monitor well on active its. 17:00 18:45 1.75 9,742 9,742 INTRM1 CEME~ CIRC P Circulate and condition mud and hole w/ Frank's fillup tool while recip casing f/ 9742' to 9722' (20' stroke). Initial circ rate 3.5 bpm increase to 6.5 bpm w/ 550 psi. initial and 470 psi final. Clear and clean floor. Lay down some casing tools. Circulate a total of 620. bbls BU+ . 18:45 19:15 0.50 9,742 9,742 INTRM1 CEME~ RURD P Rig down Frank's fillup tool. RU Dowell cement head and lines. ._ .~ _ ~_ ~~ P~~~ 2 s~f 56 Time Logs - ---- _ _ Date From To Dur S Depth - E_'Degth Phase Code Subcode T _ _ COM _; _ 12/01/2006 19:15 21:00 1.75 9,742 9,745 INTRM1 CEMEI~ CIRC P Circulate and condition mud and hole w/ Dowell cment head while recip casing f/ 9745' to 9725' (20' stroke). Pumping 7 bpm w/ 310 psi. initial and 310 psi final. Circulate a total of 650 bbls (BU+). PJSM with APC truck drivers, crew and Dowell while circulating. Total fluid circulated prior to cment while on bottom = 1270 bbls. Initial mud properties: Wt 9.5 ppg, PV/YP 11!20, FV 48, gels 10/29/35. Final mud properties Wt. 9.5 ppg, PV/YP 13/14, FV 41, gels 9/24/29. PU wt 320k, SO wt 110k. 21:00 23:00 2.00 9,745 9,745 INTRM1 CEME~ OTHR P Dowell pump 5 bbls water, test lines to 3500 psi, mix and pump @ 5 bpm w/ 340 psi, 50 bbls CW 100 (8.3 ppg), 76.5 bbls mud push @ 11 ppg, drop bottom plug, mix and pump @ 4.7 bpm 304 bbls (750 sx) DeepCrete cement (12.5 ppg, 2.24 yeild, 7.485 gal/sx water) with initial pressure of 412 psi final of 500 psi, drop top plug, follow w/ 5 bbls water. Turn over to Rig for displacement. Continue to recip casing f/ 9745' to 9725'. PU wt 310k, SO wt 110k. 23:00 00:00 1.00 9,745 9,730 INTRM1 CEME~ DISP P Rig displace cement w/ 8.7 ppg oil base mud. Displace @ 6 bpm w/initial pressure of 140 psi. 401.6 bbls pumped @ midnight (cement almost to the shoe). Pumping 6 bpm w/ 350 psi @ midnight.. While reciprocating pipe f/ 9745' to 9725', pipe did not want to go down, after pumping 120 bbls oil base mud. PU wt was 360k, SO became block wt (70k). Pipe was approx 10' above where planned setting depth was. Continued to try to work pipe, with no success going down. _~ ~~e F's~~ s ,~f ~ti { __ Time-Logs . - _ -- Date From To Dur S Depth E. De th Phase Code Subcode T COM___ 12/02/2006 00:00 01:00 1.00 9,730 9,730 INTRM1 CEME~ DISP P Rig continued to displace cement w/ 8.7 ppg oil base mud. Displace @ 6 bpm w/ initial pressure of 140 psi, final 1100 psi prior to slowing to 3 bpm 16.7 bbls prior to bumping plug (712.84 bbls pumped). Pumping 3 bpm w/ final of 950 psi before bumping plug to 1450 psi. Full returns throughout job. Bumped plug @ 7267 strokes (729.6 bbls) While reciprocating pipe f/ 9745' to 9725', pipe did not want to go down, after pumping 120 bbls oil base mud. PU wt was 360k, SO became block wt (70k). Pipe was approx 10' above where planned setting depth was. Quit trying to work pipe after pumping 673 bbls. CIP 12/2/2006 0100 hrs. 01:00 01:30 0.50 9,730 9,730 INTRM1 CEME~ OTHR P Hold 1450 psi f/ 5 min. Bleed pressure, check floats, OK. Rig down Dowell cement head. 01:30 03:00 1.50 9,730 9,730 INTRM1 CEME~ OTHR P Rig down flowline while trying to evacuate the,fluid f/inside of landing joint. Loosen up the turn buckles to the stack. Cleanin its. 03:00 04:30 1.50 9,730 9,730 INTRM1 WELCT NUND P PU BOP stack w/bridge cranes. Center casing in hole f/ setting emergency slips. Continue cleaning its. 04:30 05:00 0.50 9,730 0 INTRM1 CASIN( OTHR P Slack off, setting 280k on Vetco Gray emergency slips (blocks 70K of this wt . 05:00 06:00 1.00 0 0 INTRM1 CASIN< RURD P Cut casing wNetco Gray pneumatic casing cutter (made by DLRICCI Corp). Remove Jt # 212 and cutoff of jt # 211 16.76') 06:00 06:30 0.50 0 0 INTRM1 WELCT OTHR P Clean and dress metal f/ cutoff. Install Vetco Gra ackoff. 06:30 07:00 0.50 0 0 INTRM1 WELCT NUND P Lower wellhead and BOP stack to casing spool. Tighten bolts on Vetco Gra multibowl. 07:00 07:15 0.25 0 0 INTRM1 WELCT OTHR P Inject plastic into void of packoff. 07:15 07:45 0.50 0 0 INTRM1 WELCT OTHR P Test packoff to 80 percent of collapse of 9-5/8" 40 ppf L-80 (3090 psi). Test to 250, hold f/ 10 min, test to 2500 si, hold f/ 10 min. OK. 07:45 08:00 0.25 0 0 INTRM1 DRILL SFTY P PJSM on RU and performing injectivity test on 13-3/8" x 9-5/8". 08:00 09:00 1.00 0 0 INTRM1 DRILL RURD P Thaw line f/mud pump #1 to cellar to perform injectivity test. Pump water through line. RU lines and chart recorder for test. Rig up on lower annulus w/mud pump via secondary kill line. Cleanin its. -~ ~ _ e ~e~ ______.~ l t~~~~~ 2~ of ~__ __0. ~. __. ~ ~ . -__ __...__.._.._._ _.._._.._ m _.__._.._____..._......_._. ~_~__.~ Time Lois Date From l'o Dur S. De th E. De th Phase Code Subcode T COM 12/02/2006 09:00 10:15 1.25 0 0 INTRM1 DRILL LOT P Perform infectivity test on 13-3/8" x 9-5/8". Estimated top of cement 5495' (2687' TVD). 13-3/8" shoe @ 3501' (2196' TVD). 9.6+ ppg mud in annulus. Pump @ 5 spm. Shut in pressure 510 psi, bleed of to 390 psi in 10 minutes. Follow test w/flush of total of 40 bbls water pumped @ 16-22 spm, final pressure 650 psi after pumping 40 bbls. 10:15 11:15 1.00 0 0 INTRM1 DRILL OTHR P Bleed of lines. Blow down lines. Clean and straighten up in cellar. Loading tools in pipe shed. Cleaning pits. Greasing choke manifold valves and manual valves on stack. 11:15 12:00 0.75 0 0 INTRMI WELCT NUND P Rig up flow line. Rig up hole fill line. Ti hten turn buckes to the stack. 12:00 13:30 1.50 0 0 INTRM1 CASIN( RURD P Lay down casing tools from rig floor. Clear and clean floor. Checked saver sub on top drive, OK. RU short bales f/ drillin .Install 5" elevators. 13:30 14:45 1.25 0 0 INTRM1 DRILL PULD P Pickup smaller components f/ BHA #4 to the floor. Bring short MWD tools up beaver slide, then down to i e shed. 14:45 15:00 0.25 0 0 INTRM1 WELCT SFTY P PJSM on BOP test. 15:00 16:00 1.00 0 0 INTRM1 WELCT OTHR P Rig up for BOP test. Set test plug. Fill stack and choke manifold with water. 16:00 19:00 3.00 0 0 INTRM1 WELCT BOPE P 2 week BOPE test. Test to 250 psi low and 3000 psi high. Hold each test 5 min. Test accumulator. Test gas alarms. 19:00 20:00 1.00 0 0 INTRM1 WELCT OTHR P Pull test plug. Rig down test equipment. Blow down kill and choke lines. Install Vetco Gray wear bushing. Continue cleaning pits and loading i e shed. 20:00 20:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on PU/MU BHA # 4. 20:15 21:45 1.50 0 0 INTRM1 WELCT OTHR P Rig up geopilot skid on floor. Rig floor to PU tools f/ i e shed. 21:45 23:45 2.00 0 295 INTRM1 DRILL PULD P MU BHA #4. 23:45 00:00 0.25 295 295 INTRM1 DRILL OTHR P Shallow test Sperry Sun MWD tools. 12/03/2006 00:00 05:30 5.50 295 3,607 INTRM1 DRILL PULD P PU 5" drill pipe from pipe shed and run in hole w/ BHA #4. Fill pipe every 20 stands. Break in seals on geopilot @ 3607'. Pum in 570 m w! 600 si. 05:30 08:00 2.50 3,607 3,607 INTRM1 DRILL SFTY P Table top stripping drill. A drill for each crew. 08:00 10:15 2.25 3,607 4,286 INTRM1 DRILL PULD P PU 5"drill pipe from pipe shed and run in hole w/ BHA #4. Fill pipe every 20 stands. Rabbit i e to 2.50". .e___~ _____-.__~ _ ~ W _~~~ sa P~~ , ,~1 Time Logs Date From To Dur S~Depth E. Depth -Phase Code Subcode T _ COM __ __ 12/03/2006 10:15 10:45 0.50 4,286 4,286 INTRM1 DRILL OTHR P Remove thread protectors from floor. Fill trip tank. Barricade cellar area in preparation for wells group to try and gas lift well 1J-137, which is right outside the cellar on the driller's side. 10:45 14:30 3.75 4,286 7,597 INTRM1 DRILL PULD P Continue to PU 5"drill pipe from pipe shed and run in hole w/ BHA #4 (/4286' to 7507'. Fill pipe every 20 stands. Rabbit i e to 2.50". 14:30 15:00 0.50 7,597 7,597 INTRM1 DRILL OTHR P Rig down skate on floor. Fill pipe. Check MWD tools 7597'. 15:00 17:00 2.00 7,597 9,600 INTRM1 DRILL TRIP P RIH w/ BHA #4 on 5" dp from derrick from 7597' to 9600'. 17:00 17:15 0.25 9,600 9,637 INTRM1 DRILL CIRC P Make a top drive connection, fill pipe, to cement 9637'. 17:15 18:45 1.50 9,637 9,596 INTRM1 DRILL CIRC P Circulate and condition mud @ 9625', stagging pumps up to 600 gpm w/ 2900 psi. Rotate 30-60 rpm w/ 9-13k ft Ibs for ue. Stand back a stand 18:45 19:30 0.75 9,596 9,596 INTRM1 CASIN( DHEQ P Rig up to test 9-5/8" 40 ppf L-80 BTC-m casing. Circ through kill line. Use u er i e rams 3-1/2" x 6" . 19:30 20:15 0.75 9,596 9,596 INTRM1 CASIN( DHEQ P Test 9-5/8" 40 ppf L-80 BTC-m casing to 3000 psi. Chart test. 30 minute casin test. 20:15 20:30 025 9,596 9,596 INTRM1 CASINC DHEQ P Bleed off pressure. Measure volume bleed back. Blow down lines. 20:30 21:15 0.75 9,596 9,596 INTRM1 RIGMN SVRG P Service rig, crown, top drive and travelin a ui ment. Check saver sub. 21:15 23:30 2.25 9,596 9,745 INTRM1 CEME(` COCF P Make a top drive connection, tag cement, drill cement, plugs @ 9645' (DPM), FC @ 9647' (DPM), cement to FS @ 9732' (DPM). Then drilling rat hole f/ 9733' to 9749' (DPM). Drill w/ 6-8k WOB, 550 gpm w/ 2550 psi. Rotate 90 m w/ 8-14k ft Ib for ue. 23:30 00:00 0.50 9,745 9,760 INTRM1 DRILL DDRL P Drill new hole from 9749' to 9760' @ midnight. Pumping 550 gpm w/ 2550 psi. Rotate 90 rpm w/ 8-14k ft Ib torque. WOB 6-8k. ADT = .45 hrs, jar hrs 71.71 hrs Appeared to hit a concretion while drillin 9759'. 12/04/2006 00:00 00:30 0.50 9,760 9,770 INTRM1 DRILL DDRL P Drill 8-1/2" hole f/ 9760' - 9770'. Pumping 550 gpm w/ 2550 psi. Rotate 90 rpm w/ 8-14k ft Ib torque. WOB 6-8k. Bit hrs .66 hrs, ADT = .21 hrs, ~ar hrs 71.92 hrs 00:30 00:45 0.25 9,770 9,695 INTRM1 DRILL TRIP P POOH f/ 9770' to 9695'. 00:45 01:15 0.50 9,695 9,695 INTRM1 DRILL CIRC P MU top drive. Pumping 550 gpm w/ 2550 psi. Rotate 90 rpm w/ 10k ft Ib torque. PU wt 215k, SO wt 105k, Rot wt 135k. Work strin f/ 9695' to 9600'. 01:15 01:45 0.50 9,695 9,695 INTRM1 DRILL OTHR P Blow down top drive. RU to perform LOT. Circulate through kill line. Close u er ipe rams. P~~e 2€a zit his C~ C~ Time Logs __ _ - Date From To Dur S. De th E. De th Phase Code Su6ccde T _ COM _ 12/04/2006 01:45 02:15 0.50 9,695 9,695 INTRM1 DRILL LOT P Perform LOT w/ 8.7 ppg mud weight 02:15 02:45 0.50 9,695 9,695 INTRMI DRILL OTHR P Bleed off pressure, measure fluid bleed back to trip tank. Rig down e ui ment. 02:45 03:45 1.00 9,695 9,695 PROD1 RIGMN SVRG P Change out 4-1/2 IF saver sub. 03:45 05:00 1.25 9,695 9,695 PROD1 RIGMN SVRG P Slip and cut drilling line. Cut 94'. Ins ect brakes. 05:00 06:00 1.00 9,695 9,770 PROD1 DRILL OTHR P Make up stand, perform PWD baseline. 8.7 MW: pumping 580 gpm, 0 rpm (10.22 ppg), 60 rpm (10.3 ppg) ppg clean hole. 75 rpm (10.35 ppg), 90 rpm (10.41ppg) 8.7 MW: pumping 600 gpm, 0 rpm (10.28 ppg), 60 rpm (10.32 ppg) ppg clean hole. 75 rpm (10.37 ppg), 90 rpm (10.35 ppg) 8.7 MW: pumping 630 gpm, 0 rpm (10.3 ppg), 60 rpm (10.33 ppg) ppg clean hole. 75 rpm (10.32 ppg), 90 rpm (10.44 ppg) Obtain SPR's. 06:00 00:00 18.00 9,770 11,506 PROD1 DRILL DDRL P Drill 8-1/2" prod f/ 9770' to 11506' (TVD 3563'). Jar hrs 84.47. ECD's 10.23 ppg to 10.9 12/05/2006 00:00 03:00 3.00 11,506 11,749 PROD1 DRILL DDRL P Drill 8-1/2" "B"production hole f/ 11506' to 11749' (TVD 3557). Jar hrs 86.35. ECD's 10.76 ppg to 10.9 ppg. Observed swivel ackin leakin . 03:00 03:15 0.25 11,749 11,593 PROD1 DRILL TRIP T POOH f/ 11749' to 11593'. 03:15 04:00 0.75 11,593 11,593 PROD1 RIGMN RGRP T Work on swivel packing. Grease and tighten nut. Check and still leaking. Clean u . 04:00 05:00 1.00 11,593 10,640 PROD1 DRILL TRIP T POOH f/ 11593' to 10640'. Monitor well on tri tank. 05:00 05:30 0.50 10,640 10,640 PROD1 RIGMN RGRP T Change swivel packing. 05:30 05:45 0.25 10,640 10,640 PROD1 DRILL TRIP T Pump 620 gpm w/ 2900 psi. Backream f/ 10640' to 10545', then back to 10640'. 05:45 06:00 0.25 10,640 10,830 PROD1 RIGMN RGRP T Pressure test packing to 3500 psi. OK. RIH f/ 10640' to 10830'. 06:00 07:30 1.50 10,830 11,749 PROD1 DRILL REAM T Wash & ream in the hole f/ 10830' to 11749' (No 50 wt). Pumps @ 600 GPM's - 2900 PSI. 90 RPM's. TO @ 13K. 07:30 12:00 4.50 11,749 11,872 PROD1 DRILL DDRL P Continue directional drill 8 112" hole from 11749' - 11872' (123'). Drilling 32' of concretions. ADT = 4.20 HRS • C~ lime Logs -- _ _ - Date _ From To bur _ S. Depth E. De th _ Phase Code Subcode T COM _ _ ____ ___ 12/05/2006 12:00 18:00 6.00 11,872 12,450 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 11872' - 12450' (578'). Drilling 10' of concretions. ADT = 4.16 HRS. SIMOPS: Rig up Little Red Services and flush annulas w/ 160 bbls fresh water (Grand total of 200 bblsfresh water) and freeze protect the 9 5/8" x 13 3/8" annulus with 120 BBLs of diesel. RD Little Red. Shut in Press = 675 PSI. 18:00 00:00 6.00 12,450 12,734 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 12450' - 12734' (284'). Drilling 33' of concretions. ADT = 4.54 HRS. 12/06/2006 00:00 06:00 6.00 12,734 13,401 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 12734' - 13401' (667'). Drilling 15' of concretions. ADT = 4.45 HRS. 06:00 12:00 6.00 13,401 13,988 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 13401' - 13988' (587'). Drilling 10' of concretions. ADT = 3.71 HRS. Note; Hole begin to show losses @ 13400' initial rate 30 bph. Lower pump rate to 580 m 12:00 18:00 6.00 13,988 14,459 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 13988' - 14459' (471'). Drilling 17' of concretions. ADT = 3.79 HRS. Total fluid losses to formation 90 bbls. Pump rate 580 gpm. Well breathing sli htl on connections 18:00 00:00 6.00 14,459 14,666 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 14459' - 14666' (207'). Drilling 48' of concretions. ADT = 5.24 HRS. 0 losses to formation. Pump rate 580 gpm. Well breathing slightly on connections. 12/07/2006 00:00 06:00 6.00 14,666 15,210 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 14666' - 15210' MD (544'). Drilling 19' of concretions. ADT = 4.66 HRS. 0 losses to formation. Pump rate 580 gpm, ECD = 11.4 Well breathing sli htl on connections. 06:00 12:00 6.00 15,210 15,781 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 15210' - 15781' MD (571'). Drilling 5' of concretions. ADT = 3.71 HRS. 0 losses to formation. Pump rate 580 gpm. ECD = 11.19, Well breathing sli htl on connections. 12:00 18:00 6.00 15,781 16,226 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 15781' - 16226' MD (445'). Drilling 17' of concretions. ADT = 3.50 HRS. 0 losses to formation. Pump rate 600 gpm. ECD = 11.63 Well breathin sli htl on connections. ~~ ~ - ~ ~ P~rt~ a~f ~~i ~ • • Time Lo s 9 ---- --_ - -- Date From To Dur S Depth E De th Phase Code Subcode T COM 12/07/2006 18:00 00:00 6.00 16,226 16,799 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 16226' - 16799' MD (573'). ADT = 4.05 HRS. Pump Rate 605 gpm. ECD = 11.0. Well breathing slightly on connections. Total loss to well today = 49 BBLS 12/08/2006 00:00 06:00 6.00 16,799 17,068 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 16799' - 17068' MD (269'). ADT = 3.69 HRS. Change out chokes on Geo Span unit to better signal Geo Pilot. Crew Chan e 06:00 12:00 6.00 17,068 17,295 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 17068' - 17295' MD (227'). ADT = 4.31 HRS. 12:00 15:00 3.00 17,295 17,507 PROD1 DRILL DDRL P Continue directional drill 8 1/2" hole from 17295' - 17507' MD (212'), TVD = 3489'. ADT = 4.31 HRS. TD as per Geologist & DD. No fluid loss today while drillin . 15:00 16:30 1.50 17,507 17,507 PROD1 DRILL CIRC P Circulate & condition mud. pumps @ 600 GPM's - 3580 PSI. Reciprocate & rotate drill string. UP WT = 235K, SO WT = 115K, ROT WT = 122K. 16:30 18:00 1.50 17,507 17,507 PROD1 DRILL CIRC P Mix & pump 30 BBLS Hi Visc weighted sweep @ 10.4 PPG. Continue reciprocate & rotate drill strin .Crew Chan e 18:00 22:15 4.25 17,507 17,507 PROD1 DRILL CIRC P Continue pump 30 BBLS Hi visc weighted sweep @ 10.4 PPG. Reciprocating & rotating drill string. Monitor well - no losses Final ECD = 11.35 PPG before displacement. SIMOPS: Load vac trucks with SFMOBM, spot & rig up for dis lacement. 22:15 00:00 1.75 17,507 17,507 PROD1 DRILL CIRC P Held PJSM with crew, Mud engineer & vac truck drivers. Designate spill champion. Discuss safety issues and procedure for displacement. Line up and begin displacement with 8.7 PPG SFMOBM @ 6.5 BPM, continuing to reciprocate & rotate drill string. Observe drill string RPM's stalling @ 24K Torque when SFMOBM coming u annulus. ~ ~e ~e _ _ ~~~ 2 of ~ • Time Lam- -- - - Date __ _ _From To Dur _ __ S,_Depth_ _E, Depth - Phase Code Subcode T COM 12/09/2006 00:00 02:45 2.75 17,507 17,507 PROD1 DRILL CIRC P Complete displacement with 8.7 PPG SFMOBM @ 6.5 BPM, continuing to reciprocate & rotate drill string. Dropped 2 1/8" ball with 100 BBLs left to displace, allow to fall pumping ball down @ 3 BPM to seat & pressure to 2100 PSI to open. Observe drill string RPM's stalling @ 24K Torque when SFMOBM coming up annulus. Increase torque limit to 25K, and slow RPM's to 100, observing better rotation of drill string. No Fluid loss while dis lacin . 02:45 03:00 0.25 17,507 17,507 PROD1 DRILL OWFF P Pumps off, monitor well -fluid falling. Blow down To Drive & lines. 03:00 06:00 3.00 17,507 14,070 PROD1 DRILL TRIP P POOH on elevators, 10-20 ft/min for 5 stands. Observe proper hole fill, and upweight 330-390K falling back to a stadey pull of 330-350K. Increase pulling speed to 30-50 ft/min observing good pipe movement with up weight @ 330 - 350K, with Proper hole fill. Trip from 17507' - 14070'. Drill string pulling d .Crew Chan e 06:00 09:45 3.75 14,070 9,600 PROD1 DRILL TRIP P Continue POOH on elevators from 14070' - 9600'. Obtain T&D parameteras as per rig engineer. Monitor well -static. 09:45 10:00 0.25 9,600 9,600 PROD1 RIGMN SFTY P Held PJSM with crew. Discuss safety issues and procedure for slipping & cuttin drillin line & servicin ri . 10:00 11:00 1.00 9,600 9,600 PROD1 RIGMN SVRG P Service draw works, grease crown section. 11:00 12:00 1.00 9,600 9,600 PROD1 RIGMN SVRG P Slip & cut 119' of drilling line. Inspect & ad~ust brakes. 12:00 17:45 5.75 9,600 940 PROD1 DRILL TRIP P Continue POOH on elevators from 9600' - 940': Pulling dry. Observe proper hole fill. Record T&D arameters as er ri en ineer. 17:45 18:00 0.25 940 402 PROD1 DRILL TRIP P Pull air slips from rotary table. Breakout & lay down Ghost reamer. Continue POOH to 402'. (BHA). Ghost reamer gauged to 8 1/2" OD. Crew Chan e 18:00 20:30 2.50 402 0 PROD1 DRILL PULD P Continue POOH ,breakout & lay down BHA. Inspect & grade bit to 2/1/CT/I/X/I/NO/TD. Total fluid loss while POOH = 0 BBLS. 20:30 00:00 3.50 0 0 COMPZ EVALV~ DHEO P Held PJSM with SWS reps & rig crew. Discuss safety issues and procedure for rig up and run USIT log. Rig up wireline unit & pull tools to floor. Make up USIT logging tools. WLIH with USIT tools on tractor as per SWS from surface to 4500' MD. Prepare 5 1/2" liner in i e shed. j P~~ ~D c~i • Time Logs Date From To Dur S. De th E. De tp h .Phase Code Subcode T COM _ ___ __ 12/10/2006 00:00 04:45 4.75 0 0 COMPZ EVALVI~ DHEQ P Continue WLIH with USIT logging tools on tractor from 4500' MD to 9737' MD 5' below shoe). Continue prepare 5 1/2" liner in pipe shed. Fluid loss = 2-3 BBLS/HR Crew Chan e 04:45 06:00 1.25 0 0 COMPZ EVALV6 DHEQ P WLOH with tractor &USIT log from 9737'as per SWS. Continue prep 5 1/2" liner. 06:00 08:00 2.00 0 0 COMPZ EVALVI~ DHEQ P Continue WLOH with tractor &USIT log from 9737'as per SWS. Continue re 5 1/2" liner. 08:00 09:00 1.00 0 0 COMPZ EVAL1l~ RURD P Rig down SWS wireline services. 09:00 09:30 0.50 0 0 COMPZ WELCT BOPE P Perform weekly function test of BOP's egipment. Record on IADC. Blow down all lines. 09:30 11:30 2.00 0 0 COMPZ CASIN( RURD P Held PJSM with rig crew and GBR reps. Discuss safety issues and procedure for rigging up. Rig up alt liner running equipment. Pull centralizers to floor. 11:30 12:00 0.50 0 0 COMPZ CASIN( SFTY P Held PJSM with rig crew, Co. Man, TP, BOTand GBR reps. Discuss safety issues and procedure for runnin 5 1/2" liner assembl 12:00 18:00 6,00 0 6,714 COMPZ CASIN( RNCS P Make 5 1/2" shoejoint and shoe. Continue RIH wioth 5 1/2" slots & blanks as per detail to 6714' MD. Obtain T&D parameters as per rig engineer every 10 joints in cased hole. Crew than e 18:00 21:00 3.00 6,714 8,307 COMPZ CASIN( RNCS P Continue RIH wioth 5 1/2" slots & blanks as per detail to 8307' MD. Obtain T&D parameters as per rig engineer every 10 joints in cased hole. Make up HRD Liner Top pcker & Flexlock Liner hanger as per BOT rep. Fluid loss 2-3 BBLS / HR. 21:00 00:00 3.00 8,307 11,550 COMPZ CASIN( RUNL P Continue TIH with 5 1/2" liner on 5" drill string from 8307' - 11637' MD. Continue obtain T&D parameters as per rig engineer every 5 stands. Total fluid loss for the da = 42 BBLS. 12/11/2006 00:00 06:00 6.00 11,637 17,061 COMPZ CASIN( RUNL P Continue TIH with 5 1/2" liner on 5" drill string from 11637' - 17061' MD. Begin rotating @ 11637' down each stand as we ran out of downweight. Turn drill string & liner @ 20-40 RPMs' - 10-18K torque. Continue obtain T&D parameters as per rig engineer every 5 stands. Fluid losses = 1 BBUHR Crew Chan e 06:00 06:45 0.75 17,061 17,495 COMPZ CASINC RUNL P Continue rotate 5 1/2" liner in hole from 17061' - to tag bottom @ 17512'. Pick up string to set on depth as per detail 17495' MD. _ _ _ - -- i _ ;~cqe 3 3 r>9 r E -_..~ • • Time Logs Date From To _ Dur__S. Depth E._Depth Phase Code Subcode T COM 12/11/2006 06:45 07:15 0.50 17,495 17,495 COMPZ CASIN( CIRC P Break circulation @ 4.5 BPM - 350 PSI. UP WT = 275K, SO WT = 72K, ROT WT = 135K. 07:15 09:00 1.75 17,495 9,197 COMPZ CASIN( CIRC P Drop 1 3/4" ball. Pump ball down at rates of 4.5 BPM - 350 PSI, slowing to 2 BPM - 110 PSI. Observe ball land & seat. Continue pressure to 2300 PSI, observing packer set, Slack off to 70K. Pressure to 3600 to observe liner hanger set, then to 4000 PSI. Bleed pressures. Pull drill string up to 150K, Observed released. Rig up & test annulus to 1450 PSI - 10 Minutes. Bleed pressures. Pull up, then slack off to confirm Liner top @ 9197' MD. Pressure to 1000 PSI, pull out of liner, confirmed free of liner. 09:00 10:15 1.25 9,197 9,085 COMPZ CASIN( CIRC P Rack Back 1 stand. Circulate bottoms up @ 315 GPM's - 625 PSI. No fluid loss. 10:15 10:30 0.25 9,085 9,085 COMPZ CASINC CIRC P Monitor well 10 minutes -static. 10:30 11:00 0.50 9,085 9,085 COMPZ CASINC OTHR P Blow down Top drive & lines. Install air sli sin rota table. 11:00 12:00 1.00 9,085 7,800 COMPZ CASINC RUNL P POOH with drill string from 9085' - 7800'. 12:00 14:45 2.75 7,800 0 COMPZ CASINC RUNL P Continue POOH with drill string from 7800' -surface. 14:45 15:30 0.75 0 0 COMPZ CASINC RUNL P Inspect & breakout BOT running & settin tools. La down same. 15:30 16:30 1.00 0 0 COMPZ CASINC OTHR P Clean & clear rig floor of all liner running equipment. Lay down remainin centralizers from ri floor. 16:30 16:45 0.25 0 0 PROD2 STK OTHR P Held PJSM with crew & BOT rep. Discuss safety issues and procedure for picking up tools and making up whi stock BHA. 16:45 18:00 1.25 0 0 PROD2 STK PULD P Make up 9 5/8" Whipstock assembly as er BOT re .Crew Chan e 18:00 20:00 2.00 0 0 PROD2 STK PULD P Continue MU 9 5/8" Whipstock assembl as er BOT re . 20:00 20:45 0.75 0 0 PROD2 STK PULD P Make up MWD assembly. Orient MWD to whipstock face. Offset = 200.89 De . 20:45 21:30 0.75 0 0 PROD2 STK OTHR P Plug in and Upload MWD assembly. 21:30 22:15 0.75 0 0 PROD2 STK PULD P Make up remaining Whipstock BHA, Bumperjar, Flex DC's, and 5" HWDP as er BOT re . 22:15 22:30 0.25 0 501 PROD2 STK OTHR P Rig up and perform shallow pulse test. Pumps @ 585 GPM's - 1050 PSI. Blow down Top drive & lines. Total BHA len th = 501'. 22:30 22:45 0.25 501 691 PROD2 STK TRIP P Trip in hole with whipstock assembly from 501' - 691' MD. ____~ ~~ _~ ~_~.® ______.l { P~~~ ~~ s~f ~~ 1~ ~~ ~~ Time Lo s __ ~- -9- __ ._--- Date From To Dur S. De th E. De th Phase Code Subcode T COM _- T - - - 12/11/200622:45 00:00 1.25 691 691 PROD2 RIGMN SVRG P Held PJSM with crew. Discuss safety issues and procedure for changing out Top drive saver sub. Change out saver sub. 12/12!2006 00:00 00:15 0.25 691 691 PROD2 RIGMN SVRG P Complete change out of Top Drive saver sub. 00:15 06:00 5.75 691 8,303 PROD2 STK TRIP P Continue trip in hole with 9 5/8" Whipstock assembly @ 2 minutes / stand as per BOT rep. Fill drill string every 30 stands. Fluid losses = 1-2 BBLS /HR. Crew Chan e 06:00 06:15 0.25 8,303 8,377 PROD2 STK TRIP P Continue TIH with whipstock assembly from 8303' - 8377' @ 2 minutes / stand. 06:15. 06:45 0.50 8,377 8,404 PROD2 EVALVI~ OTHR P Perform MAD PASS log from 8377' -8404' MD as er MWD and Geolo ist. 06:45 07:45 1.00 8,404 9,149 PROD2 STK TRIP P Contiue TIH with whipstock assembly from 8404' - 9149'. 07:45 08:00 0.25 9,149 9,149 PROD2 STK CIRC P Make Top drive connection and obtain circulation. 08:00 08:30 0.50 9,149 9,149 PROD2 STK OTHR P Orient whipstock face to 7 degrees left of high side as per DD & Co. Man. Pumps @ 300 GPM's - 800 PSI. UP WT = 235K, SO Wt = 90K. 08:30 09:00 0.50 9,149 9,084 PROD2 STK OTHR P Tag top of B lateral liner at 9202' (5' Deep). set seals into liner top and set BTA. Pull 10K over to verify set. Attempt to shear bolt. Unsuccessful with SFMOBM in hole. Not enough downweight. Top of whipstock at 9084'. 09:00 10:00 1.00 9,084 9,084 PROD2 STK CIRC P Displace out SFMOBM with OBM @ 450 GPM's - 1600 PSI. 10:00 10:45 0.75 9,084 9,084 PROD2 STK OTHR P Shear off whipostock bolt with 50K set down weight. Pick up to neutral position, rotate free with 90 RPM's - 10Kfor ue. 10:45 12:00 1.25 9,084 9,088 PROD2 STK OTHR P Mill window in the 9 5/8" casing from 9084' - 9088'. 12:00 17:15 5.25 9,088 9,130 PROD2 STK OTHR P Continue mill window from 9088' - bottom of window @ 9100'. Mill in Open hole to 9130' MD. Pump weighted Hi Visc sweeps as necessa . 17:15 18:00 0.75 9,130 9,130 PROD2 STK CIRC P Pump 40 BBL Hi Visc weighted sweep and work mills through window area to clean up window. UP WT = 210K, SO WT = 122K, ROT WT = 130K. Crew Chan e 18:00 18:15 0.25 9,130 9,130 PROD2 STK CIRC P Continue pump 40 BBL Hi Visc weighted sweep and work mills through window area to clean up window. UP WT = 210K, SO WT = 122K, ROT WT = 130K. Pump Rate 600 GPM's - 2400 PSI. ~ m®m _~~ _~ ~ _ ~ J Time Logs ~- - _- - . Date From To Dur S. De th E. De th Phase Code Subcode T COM_ 12/12/2006 18:15 18:30 0.25 9,130 9,130 PROD2 STK OTHR P Work mills through window with no pumps or rotation. Observe clean window. 18:30 19:00 0.50 9,130 9,130 PROD2 STK OTHR P Observe well for 15 minutes -static. Pump dry job. Blow down Top drive & lines. 19:00 22:00 3.00 9,130 3,712 PROD2 STK TRIP P POOH on elevators from 9084' - 3712' MD. Observed ro er hole fill. 22:00 00:00 2.00 3,712 2,100 PROD2 STK TRIP P Continue POOH inspecting, moving and replacing Super Slideras as needed. Pull from 3712' - 2100'. Strap DP on TOH. 12/13/2006 00:00 02:45 2.75 2,100 383 PROD2 STK TRIP P Continue POOH inspecting, moving and replacing Super Sliders as needed. Pull from 2100' - 383'. Replaced a total of 8 sleeves and 27 collars on the su er sliders. 02:45 03:30 0.75 383 83 PROD2 STK PULD P Stood back 2 stands of 5" HWDP & 1 stand of flex drill collars. lay down Bum er'ar. 03:30 04:15 0.75 83 83 PROD2 STK OTHR P Plug in and down load MWD assembl . 04:15 05:15 1.00 83 0 PROD2 STK PULD P Continue POOH break out & lay down BHA. Inspect & gauge mills to full au a of 8.5". 05:15 05:45 0.50 0 0 PROD2 STK PULD P Clean & clear floor area, send tools outside. Brin tools to floor. 05:45 06:00 0.25 0 0 PROD2 WELCT BOPE P Rig up & pull Wear bushing. Crew chan e. 06:00 07:00 1.00 0 0 PROD2 WELCT OTHR P Rig up stack washing tool, and flush BOP stack of iron cuttings. Lay down tool. 07:00 07:45 0.75 0 0 PROD2 WELCT BOPE P Clean & clear rig floor. Send tools out. Hold PJSM with crew. Discuss safety issues and procedure for rigging up & testin BOP's. 07:45 08:45 1.00 0 0 PROD2 WELCT BOPE P Install test plug. Rig up test equipment & lines and test 'oints to test. 08:45 12:00 3.25 0 0 PROD2 WELCT BOPE P Test BOP's. AOGCC rep on location to witness test. 12:00 14:30 2.50 0 0 PROD2 WELCT BOPE P Continue test BOP's. AOGCC rep on location to witness test. 14:30 15:30 1.00 0 0 PROD2 WELCT BOPE T Attempt to test 3 1/2" x 6" variable bore rams. Test failed. 15:30 17:00 1.50 0 0 PROD2 WELCT BOPE P Continue test BOP's. Perform accumulator draw down test. Pull test ~oint. Test Blind rams. 17:00 18:00 1.00 0 0 PROD2 WELCT ROPE T Pull test plug. Drain BOP stack. PJSM with crew. Discuss safety issues and procedure for changing out Upper rams. Rig up and change rams. Crew chan e. 18:00 19:30 1.50 0 0 PROD2 WELCT BOPE T Continue change out upper rams. Remove 3 1/2" x 6" VBR's .Install 4 1/2" x 7" VBR's. e ~_w m_~ ~~ m. Page ~4 ~~ u Time Lo s ~- _ _ _ Date From 7o Dur S. Depth E. De th Phase _ _Code Subcode T COM 12/13/2006 19:30 22:15 2.75 0 0 PROD2 WELCT BOPE T Re-test with 5" and 5 1/2" test joints. Good tests. 22:15 23:45 1.50 0 0 PROD2 WELCT BOPE T Attempt to test with 4 1/2" test joint. Test failed. Rig up & retest with 5" test joint as per AOGCC rep. Good test. Pull & lay down test joint & pull test lu . 23:45 00:00 0.25 0 0 PROD2 WELCT BOPE P Make up & install wear bushing. RILDS. 12/14/2006 00:00 00:30 0.50 0 0 PROD2 WELCT BOPE P Blow down all choke & kill lines. Blow down mud lines. 00:30 01:15 0.75 0 90 PROD2 DRILL PULD P Held PJSM with crew, Sperry sun reps. Discuss safety issues and procedure for making up and runnung BHA# 6, 8 1!2" drilling assembly with Geo-Pilot. MU BHA. 01:15 02:00 0.75 90 90 PROD2 DRILL OTHR P Plug in and upload MWD assembly. 02:00 03:00 1.00 90 457 PROD2 DRILL PULD P Continue make up remaining BHA. Make u Centurion Circulation valve. 03:00 03:30 0.50 457 457 PROD2 DRILL PULD P Perform shallow pulse test. Good test. Pum s 550 GPM's - 1000 PSI. 03:30 06:00 2.50 457 6,169 PROD2 DRILL TRIP P Trip in hole with BHA # 6 from 457' - 6169' MD. Observed proper hole fill. Obtain T&D parameters as per rig engineer every 10 stands. Crew chan e. 06:00 08:30 2.50 6,169 9,015 PROD2 DRILL TRIP P Continue trip in hole with BHA # 6 from 6169' - 9015' MD. Observed proper hole fill. Obtain T&D parameters as per rig engineer every 10 stands. 08:30 09:30 1.00 9,015 9,015 PROD2 RIGMN SVRG P Held PJSM with crew. Discuss safety issues and procedure for slipping & cutting. Slip & cut drilling line, inspect & ad~ust draw works brakes. 09:30 10:30 1.00 9,015 9,015 PROD2 RIGMN SVRG P Service Top Drive, draw works, Blocks and crown section. Ins ect saver sub. 10:30 11:15 0.75 9,015 9,130 PROD2 DRILL TRIP P Continue trip in hole from 9015' - 9130'. Observed no issues with BHA oin throu h window area. 11:15 12:00 0.75 9,130 9,184 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D Lateral from 9130' - 9184'. ECD = 10.2 PPG. ADT = .49 HRS. 12:00 12:15 0.25 9,184 9,210 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D Lateral from 9184' - 9210'. ECD = 10.3 PPG. ADT = .12 HRS. 12:15 12:30 0.25 9,210 9,210 PROD2 DRILL CIRC T Trouble shoot MWD. Failed signals. 12:30 13:00 0.50 9,210 9,272 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D Lateral from 9210' - 9272'. ECD = 10.2 PPG. ADT = 1.01 HRS. 13:00 16:00 3.00 9,272 9,272 PROD2 DRILL CIRC T Trouble shoot MWD. Failed signals. Pull drill string into casing. Obtain ood ulses. RIH to 9272'. ,~.e._ _ _ _ __ ~ ~s~~a 2~ rsf s~ L J r~ ~ J Time Logs Date From To Dur S Depth_ E. De th Phase Code Subcode T COM 12/14/2006 16:00 18:00 2.00 9,272 9,385 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D Lateral from 9272' - 9385'. ECD = 9.85 PPG. ADT = 2.08 HRS. Crew Chan e 18:00 20:30 2.50 9,385 9,509 PROD2 DRILL DDRL P Directional drill 8 1/2" hole in the D Lateral from 9385' - 9509'. ECD = 9.93 PPG. ADT = 1.69 HRS. 20:30 00:00 3.50 9,509 3,220 PROD2 DRILL TRIP T Lost MWD signal. POOH, 5 stands. Pump dry job. Continue POOH from 9509' - 3220' Observed ro er hole fill. 12/15/2006 00:00 01:00 1.00 3,220 460 PROD2 DRILL TRIP T Continue POOH from 3220' - 460'. Observed ro er hole fill. 01:00 02:15 1.25 460 80 PROD2 DRILL PULD T Stand back Flex drill collars & HWDP. Pull to MWD assembl . 02:15 03:00 0.75 80 80 PROD2 DRILL OTHR T Plug in and down load MWD assembl . 03:00 03:30 0.50 80 0 PROD2 DRILL PULD T POOH, Break out & lay down MWD assembly. Pull to bit. Inspect & grade bit. Will rerun bit. 03:30 04:00 0.50 0 80 PROD2 DRILL PULD T RIH with Bit & Geo-Piloy assembly. Make up new MWD assembly. BHA #7. 04:00 04:30 0.50 80 80 PROD2 DRILL OTHR T Plug in and upload MWD assembly. 04:30 05:00 0.50 80 460 PROD2 DRILL PULD T Make up remaining BHA # 7. Total len th = 460.79'. 05:00 06:00 1.00 460 1,701 PROD2 DRILL TRIP T Perform shallow pulse test with pumps @ 550 GPM's - 1050 PSI. Good test. Continue TIH with BHA # 7 from 460' - 1701' MD. Crew Chan e. 06:00 06:30 0.50 1,701 1,701 PROD2 DRILL TRIP T Continue trip in hole with BHA from 1701' - 2651'. Fill drill strin . 06:30 07:30 1.00 1,701 1,701 PROD2 RIGMN SVRG T Service rig. Service Top Drive. Check swivel packing, draw works, Electrician serviced control card in the drilling console. Tested same. Good test. 07:30 11:30 4.00 1,701 9,509 PROD2 DRILL TRIP T Continue trip in hole with BHA from 1701' - 9509'. No issues passing throw h window area. 11:30 12:00 0.50 9,509 9,523 PROD2 DRILL DDRL P Directional drill in the D lateral from 9509' - 9523'. ADT = .53 HRS. ECD's = 10.1 PPG 12:00 18:00 6.00 9,523 9,972 PROD2 DRILL DDRL P Directional drill in the D lateral from 9523' -9972' MD. ADT = .4.47 HRS. ECD's = 10.1 PPG 18:00 00:00 6.00 9,972 10,573 PROD2 DRILL DDRL P Directional drill in the D lateral from 9972' - 10573' MD. ADT = .4.54 HRS. ECD's = 10.21 PPG 12/16/2006 00:00 06:00 6.00 10,573 11,208 PROD2 DRILL DDRL P Directional drill in the D lateral from 10573' - 11208' MD. ADT = 4.01 HRS. ECD's = 10.49 PPG Crew Chan e 06:00 12:00 6.00 11,208 11,653 PROD2 DRILL DDRL P Directional drill in the D lateral from 11208' - 11653' MD. ADT = 4.52 HRS. ECD's = 10.38 PPG j lea=~~ Fi of 56 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM _ _ 12/16/2006 12:00 18:00 6.00 11,653 12,255 PROD2 DRILL DDRL P Directional drill in the D lateral from 11653' - 12255' MD. ADT = 3.07 HRS. ECD's = 10.61 PPG Crew Chan e 18:00 00:00 6.00 12,255 12,826 PROD2 DRILL DDRL P Directional drill in the D lateral from 12255' - 12826' MD. ADT = 4.96 HRS. ECD's = 10.75 PPG 12/17/2006 00:00 01:00 1.00 12,826 12,990 PROD2 DRILL DDRL P Directional drill in the D lateral from 12826' - 12990' MD. ADT = .82 HRS. ECD's = 10.75 PPG 01:00 03:00 2.00 12,990 13,275 PROD2 DRILL DDRL P Directional drill in the D lateral from 12990' - 13275' MD. ADT = 1.43 HRS. ECD's = 10.97 PPG 03:00 06:00 3.00 13,275 13,586 PROD2 DRILL DDRL P Directional drill in the D lateral from 13275' - 13586' MD. ADT = 1.55 HRS. ECD's = 10.84 PPG Crew Chan e 06:00 07:00 1.00 13,586 13,707 PROD2 DRILL DDRL P Directional drill in the D lateral from 13586' - 13707' MD. ADT = .85 HRS. ECD's = 10.75 PPG Observed Geo-Pilot Failure. 07:00 07:45 0.75 13,707 13,707 PROD2 DRILL CIRC T Circulate @ 620 GPM's - 2850 PSI @ 90 RPM's troublshootin Geo-Pilot. 07:45 08:45 1.00 13,707 13,707 PROD2 DRILL CIRC T Continue circulate bottoms up @ 640 GPM's - 2850 PSI. 08:45 12:00 3.25 13,707 11,021 PROD2 DRILL TRIP T POOH due to failed Geo-Pilot on elevators from 13707' - 11021'. Pump out every 5th stand for improper hole fill. 12:00 12:30 0.50 11,021 11,021 PROD2 DRILL CIRC T Mix & pump dry job. Blow down Top Drive & lines. 12:30 13:30 1.00 11,021 9,024 PROD2 DRILL TRIP T Continue POOH on elevators from 11021' - 9024'. Observe proper. hole fill. Monitor well at window -static. 13:30 16:45 3.25 9,024 460 PROD2 DRILL TRIP T Continue POOH from 9024' - 460'. Observe proper hole fill. Record T&D parameters every 10 stands as per rig en ineer. 16:45 17:45 1.00 460 80 PROD2 DRILL PULD T Breakout & stand back BHA # 7 to MWD assembl . 17:45 18:00 0.25 80 80 PROD2 DRILL OTHR T Plug in and download MWD assembly. Calculated displacement = 101 BBLS. Actual Fill = 123 BBLS. Crew Chan e 18:00 18:30 0.50 80 0 PROD2 DRILL PULD T Continue breakout and lay down BHA # 7. Inspect & grade bit to 2/1MIT/N/X/I/NO/DTF. Plan to rerun. 18:30 19:30 1.00 0 80 PROD2 DRILL PULD T Make up BHA # 8 with rerun bit. 19:30 20:00 0.50 80 80 PROD2 DRILL OTHR T Plug in and Upload MWD assembly. 20:00 20:45 0.75 80 461 PROD2 DRILL PULD T Continue make up remaining BHA # 8. 20:45 21:00 0.25 461 461 PROD2 DRILL PULD T Perform sahllow pulse test with pumps 575 GPM's - 1075 PSI. Good test. 21:00 00:00 3.00 461 8,500 PROD2 DRILL TRIP T Trip in hole with BHA #8 from 460' - 8500' MD. Fill drill string every 25 stands. Observe ro er hole fill. i ~s 1~~~~ ~I ~~ iF~ t ~~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/18/2006 00:00 00:30 0.50 8,500 9,027 PROD2 DRILL TRIP T Continue trip in hole from 8500' - 9027'. 00:30 01:30 1.00 9,027 9,027 PROD2 RIGMN SVRG T Service rig & top drive. 01:30 02:30 1.00 9,027 9,027 PROD2 RIGMN SVRG T Held PJSM. Slip & cut 115' of drilling line. 02:30 03:15 0.75 9,027 10,100 PROD2 DRILL TRIP T Continue trip in hole from 9027' - 10100'MD. Ran out of downweight, be in wash & rotate down from 10100'. 03:15 06:00 2.75 10,100 12,390 PROD2 DRILL REAM T Wash & ream in the hole from 10100' - 12390'. MD. Pumps @ BPM - 2000 PSI. 50 RPM's. Crew Chan e 06:00 07:45 1.75 12,390 13,707 PROD2 DRILL REAM T Continue wash & ream in the hole from 12390' - 13707'. MD. Pumps @ 4 BPM - 2200 PSI. 60 RPM's. 07:45 09:45 2.00 13,707 13,968 PROD2 DRILL DDRL P Directional drill 8 1/2" hole from 13707' - 13968' MD. ADT = 1.14 HRS. ECD = 10.8 PPG. 09:45 10:45 1.00 13,968 13,968 PROD2 DRILL REAM T BROOH from 13968' - 13687'. Ream back into hole to 13968' as per Geo. Sus ect ossible STat this oint. 10:45 12:00 1.25 13,968 14,159 PROD2 DRILL DDRL P Directional drill 8 1/2" hole from 13968' - 14159' MD. ADT = 1.51 HRS. ECD = 11.1 PPG. 12:00 14:00 2.00 14,159 14,426 PROD2 DRILL DDRL P Directional drill 8 1/2" hole from 14159' - 14426' MD. ADT = 1.12 HRS. ECD = 11.1 PPG. Observed Geology issue with being low. On attempts to come up, DD observed drop in Inclination and ri ht hand walk in Azimuth. 14:00 18:00 4.00 14,426 13,500 PROD2 DRILL TRIP T Pump out of hole from 14426' - 13500'. Observe hole swabbing when attempt to POOH on elevators. Crew Chan e 18:00 18:30 0.50 13,500 13,244 PROD2 DRILL TRIP T Continue Pump out of hole from 13500' - 13244' 18:30 19:30 1.00 13,244 13,275 PROD2 DRILL DDRL T Time drill for sidetrack from 13244' - 13275' MD. Kick off at 13275'. 19:30 19:45 0.25 13,275 13,275 PROD2 DRILL DDRL T Make connection and pump up surve s. 19:45 20:45 1.00 13,275 13,398 PROD2 DRILL DDRL T Directional drill from 13275' - 13398' with 100 % deflection on the GeoPilot. Drill down full stand. Pump up survey to observe drop in inclination with 2 1/2 degrees right hand walk. Decision to POOH to change Geo-Pilot & MWD tools. 20:45 21:15 0.50 13,398 13,398 PROD2 DR1LL OTHR T Cycle pumps, obtain surveys & discuss options white reciproctae & rotate drill strip . 21:15 22:30 1.25 13,398 13,398 PROD2 DRILL CIRC T Mix & pump 35 BBL Hi Visc weighted sweep. Reciprocate & rotate drill string. Observe increase in cuttings @ 25%. 22:30 22:45 0.25 13,398 13,398 PROD2 DRILL OWFF T Monitor well. Slight flow, slowing down to sto .Well breathin . . ~ ~ ~_ ~. ~~ ~ Page 3~ cif ~ l~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T __COM ~ __ 12/18/2006 22:45 00:00 1.25 13,398 12,546 PROD2 DRILL TRIP T POOH on elevators for 3 stands. Observe well swabbing. Continue pump out of hole 15 stands. Pull from 13398' - 12546 12/19/2006 00:00 04:00 4.00 12,546 10,170 PROD2 DRILL TRIP T Continue POOH, Observe well swabbing. Continue pump out of hole from 12546' - 10170'. Observe well stopped swabbing and fluid dropping. Pumping 4 bpm w/ 450 psi. Pulling 45 ft/min. 04:00 04:15 0.25 10,170 10,170 PROD2 DRILL CIRC T Pump dry job, Blow down Top Drive & lines. 04:15 06:00 1.75 10,170 8,361 PROD2 DRILL TRIP T Continue POOH on elevators from 10170' - 8361' 06:00 08:45 2.75 8,361 461 PROD2 DRILL TRIP T Continue POOH on elevators from 8361' to 461'. 08:45 09:30 0.75 461 70 PROD2 DRILL TRIP T Stand back 5" HWDP and jars. Lay down centurian circ valve. Stand back flex drill collars and float sub. 09:30 10:00 0.50 70 70 PROD2 DRILL OTHR T Downlaod MWD. 10:00 10:45 0.75 70 0 PROD2 DRILL TRIP T Change out pulsar, UD MWD, smart stab, Gamma/Res/PWD. Check oil in eo ilot, break off bit. 10:45 11:45 1.00 0 72 PROD2 DRILL TRIP T MU BHA #9. Change jets in bit, MU bit, geopilot (TL055), nm flex DC, smart stab, Gamma/Res/PWD, MWD/HCIM and ulsar. 11:45 12:30 0.75 72 72 PROD2 DRILL OTHR T Uplaod MWD 12:30 13:00 0.50 72 455 PROD2 DRILL TRIP T MU flex DC w/ float sub, centurian valve, HWD and 'ars. 13:00 13:30 0.50 455 455 PROD2 DRILL OTHR T Shallow test MWD. Pumping 550 gpm w/ 1000 si. 13:30 17:00 3.50 455 9,023 PROD2 DRILL TRIP T Trip in hole w/ BHA #9/ Record torque and dra eve 10 stands. 17:00 17:30 0.50 9,023 9,023 PROD2 RIGMN SVRG T Blow down top drive. Service drawworks and wash i e. 17:30 19:45 2.25 9,023 9,023 PROD2 RIGMN SVRG T Inspect and change out saver sub on to drive. 19:45 20:00 0.25 9,023 9,023 PROD2 DRILL OWFF T Monitor well. OK. 20:00 21:15 1.25 9,023 10,048 PROD2 DRILL TRIP T Trip in hole. Record PU and SO wei ht's eve 5 stands. 21:15 00:00 .2.75 10,048 11,586 PROD2 DRILL REAM T Ream in hole (no down wt). 220 gpm w/ 600 si. 50 r m w/ 12-13k for ue. 12/20/2006 00:00 02:00 2.00 11,586 12,915 PROD2 DRILL REAM T Ream in hole (no down wt). 50 rpm w/ 13-14k for ue. 02:00 04:00 2.00 12,915 12,990 PROD2 STK KOST T Troughing f/sidetrack. Rotating 120 w/ 12-13k tro ue. 04:00 06:00 2.00 12,990 13,204 PROD2 DRILL DDRL T Drilling. ECD's 10.3 ppg. Jar hours 171.37. 06:00 07:30 1.50 13,204 13,333 PROD2 DRILL DDRL T Drilling. ECD's 10.3 ppg. ~.w~ - ~ _ ~ ~~~ j ~~~ :~3 ~f ors"z i i Time Lois Date From___To Dur S. De~,th E. De th Phase Code Subcode T COM _ __ _ __ ' 12/20/2006 07:30 08:00 0.50 13,333 13,333 PROD2 DRILL SRVY T Check shot survey. Survey showed unable to control Geo-Pilot (Dropping angle and hard right hand turn with strai ht u tool face). 08:00 10:45 2.75 13,333 13,333 PROD2 DRILL CIRC T Circulate 3 BU .Rotate 120 rpm w/ 15k ft Ib torque. Pumped 10 ppg 122 vis swee (sli ht increase in cuttin s 10:45 12:00 1.25 13,333 12,825 PROD2 DRILL REAM T Backream out of hole. Rotate 120 rpm w! 14k ft Ib for ue. 12:00 18:45 6.75 12,825 9,023 PROD2 DRILL REAM T Backream out of hole. Rotating 120 rpm w/ 11-14k ft Ib torque. Pulling s eed 40-45 ft/min. 18:45 20:15 1.50 9,023 9,023 PROD2 DRILL CIRC T Circulate bottom's up. Rotate 120 rpm w/ 11 k ft Ib torque. Bring (12) 5" LoTads to the rig floor, to be installed while ullin out of hole. 20:15 20:30 0.25 9,023 9,023 PROD2 DRILL CIRC T Monitor well. Pump dry job. 20:30 20:45 0.25 9,023 9,023 PROD2 DRILL OTHR T Blow down top drive. 20:45 21:15 0.50 9,023 8,359 PROD2 DRILL TRIP T Continue POOH 5"drill pipe w/super sliders, rackin on off driller's side. 21:15 21:30 0.25 8,359 8,357 PROD2 DRILL SFTY T PJSM on installing LoTads on 5"drill i e while POOH. 21:30 00:00 2.50 8,357 7,217 PROD2 DRILL TRIP T Install LoTads on 5" drill pipe while POOH. Install between bottom single and middle joint of stand. Drift LoTads w/ 2.5" drift. Total of 12 picked up @ midni ht. 12/21/2006 00:00 04:15 4.25 7,217 4,550 PROD2 DRILL TRIP T Install LoTads on 5"drill pipe while POOH. Install between bottom single and middle joint of stand. Drift LoTads w/ 2.5"drift. Total of 40 LoTads picked u. 04:15 05:30 1.25 4,550 940 PROD2 DRILL TRIP T Continue POOH w/ BHA #9. Record PU and SO weight's every 10 stands in casin . 05:30 06:00 0.50 940 459 PROD2 DRILL TRIP T Lay down 8-1/2"ghost reamer. Pull and stand back 5 stands of 5" d . 06:00 08:00 2.00 459 72 PROD2 DRILL PULD T UD BHA #9. (8) 5" HWDP, jars, Centurian circ sub, (3) nm flex dc's, and float sub. 08:00 08:30 0.50 72 72 PROD2 DRILL OTHR T Download Sperry Sun MWD. 08:30 09:15 0.75 72 0 PROD2 DRILL PULD T Continue UD BHA #9. 09:15 11:00 1.75 0 0 PROD2 WELCT EORP T Change top pipe rams f/ 4-1/2" x 7" to 3-1 /2" x 6". 11:00 11:30 0.50 0 0 PROD2 WELCT OTHR T Drain stack. Pull Vetco/Gray wear bushing. Set test plug. Fill stack with water. Pars ~4 ~f ~S , f Time Logs Date From To Dur S. De th E. De th Phase Code Subcode - T COM 12/21/2006 11:30 --- 17:00 _ 5.50 0 0 PROD2 WELCT BOPE T -- 14 day BOP test. Witness of test waived by AOGCC inspector Jeff Jones. Choke manifold and floor safety valves (4" and 5") were tested while POOH. Koomey tested. Upper pipe rams were tested w/ 4", 4-1/2", 5"and 5-1/2". Annular was tested w/ 4" pipe. Blinds were tested. Tests were held 5 min each @ 250 psi low then 3000 high. Inside kill and choke tested. Top drive IBOP tested. 17:00 18:00 1.00 0 0 PROD2 WELCT OTHR T Pull test plug, install Vetco/Gray wear bushing. Rig down test equipment. Blow down kill and choke line and choke manifold. 18:00 18:30 0.50 0 0 PROD2 RIGMN SVRG T Service drawworks, top drive and rease crown. 18:30 23:00 4.50 0 0 PROD2 DRILL PULD T Lay down 38 stands of 5"drill pipe from derrick using mouse hole in rota table. 23:00 23:15 0.25 0 0 PROD2 DRILL OTHR T Move 5 stands of 5" drill pipe f/ drillers side to DC finger on DS. This pipe is slick (no super sliders and no LoTads). PU crossovers and subs f/ BHA #10 to ri floor. 23:15 00:00 0.75 0 0 PROD2 DRILL OTHR T Move 35 stands of 5" dp w/super sliders f/ ODS to DS of derrick. 12/22/2006 00:00 00:15 0.25 0 0 PROD2 DRILL OTHR T Move 5 stands of 5" drill pipe f/ drillers side to ODS pipe rack w/ the other slick drill pipe. This pipe is slick (no su er sliders and no LoTads . 00:15 00:30 0.25 0 0 PROD2 DRILL OTHR T Change elevators to 4". Clear and clean ri floor. 00:30 00:45 0.25 0 0 PROD2 DRILL SFTY T PJSM on picking up BHA #10. 00:45 02:00 1.25 0 123 PROD2 DRILL PULD T PU/MU BHA #10. Orient motor w/ MWD. 02:00 03:00 1.00 0 93 PROD2 DRILL OTHR T Upload Sperry Sun MWD. 03:00 03:30 0.50 93 123 PROD2 DRILL OTHR T PU a 4-3/4" flex DC. Shallow test MWD tools. 59 spm (250 gpm) w/ 970 si. 03:30 03:45 0.25 123 123 PROD2 DRILL OTHR T Blow down top drive. Clean floor area. 03:45 04:00 0.25 123 185 PROD2 DRILL PULD T PU two more 4-3/4" flex collar. Chan a elevators f/ 3-1/2" to 4". 04:00 06:00 2.00 185 1,780 PROD2 DRILL PULD T Continue PU/MU BHA#10. Rabbit 4" d w/ 2-7/16" rabbit. 06:00 06:30 0.50 1,780 1,800 PROD2 DRILL PULD T MU agitator and shock sub. 06:30 07:00 0.50 1,800 1,800 PROD2 DRILL CIRC T MU top drive, fill pipe. Pump through string. 87 gpm = 800 psi, 130 gpm = 1025 psi, 181 gpm = 1175 psi-- but then pressured up to 2600 psi. Slowed rate to 87 gpm w/ 2000 psi. Excessive ressure while testin a itor. ~ ~.___ _ . ~_._ - ~~ ___e_.d__ ~ w ~ ~'~~~ ~1 of 5~a~ Time Logs _ __ Date From To Dur S Depth E Depth Phase Code Subcode T COM_ _ _ J 12/22/2006 07:00 07:30 0.50 1,800 1,780 PROD2 DRILL PULD T Lay down shock sub and agitator. MU to drive to strin . 07:30 07:45 0.25 1,780 1,780 PROD2 DRILL CIRC T Pump through string without shock sub and agitator. Pumping 168 gpm = 850 psi, 211 gpm = 1100 psi, 253 gpm _ 1400 psi, 295 gpm = 1700 psi, 316 m = 1950 si. Break out to drive. 07:45 08:00 0.25 1,780 1,800 PROD2 DRILL PULD T MU another agitator and same shock sub. Make u to drive. 08:00 08:30 0.50 1,800 1,800 PROD2 DRILL CIRC T Circulate through string. Pumping 87 gpm = 450 psi, 168 gpm = 1150 psi, 211 gpm = 1350 psi, 253 gpm = 1850 psi, 295 gpm = 2400 psi, 316 gpm = 2700 psi. Break off top drive. Blow down top drive. Agitator seems to be O K. 08:30 10:30 2.00 1,800 4,170 PROD2 DRILL PULD T Continue in the hole picking up 4" dp f/ i e shed. 10:30 14:00 3.50 4,170 9,000 PROD2 DRILL TRIP T Change elevators f/ 4" to 5". PU Centurian circ valve w/ ball catcher. Then trip in from out of derrick to 7024'. Record PU and SO weight's every 10 stands in casing. Fill pipe eve 25 stands. 14:00 15:15 1.25 9,000 9,000 PROD2 RIGMN SVRG T Slip and cut 102' of 1-3/8" drilling line. 15:15 16:15 1.00 9,000 9,000 PROD2 RIGMN SVRG T Service top drive and drawworks. 16:15 18:00 1.75 9,000 10,828 PROD2 DRILL TRIP T Continue trip in hole. Shallow test MWD, good. Record PU and SO weight's every 5 stands in open hole. Fill i e eve 20 stands. 18:00 20:30 2.50 10,828 13,302 PROD2 DRILL TRIP T Continue trip in hole. Record PU and SO weight's every 5 stands in open hole. Fill i e eve 20 stands. 20:30 21:30 1.00 13,302 13,302 PROD2 DRILL CIRC T Fill pipe. SPR's @ 13302'. Survey. Rotate to tag fill bottom. Tagged @ 13302' w/o rotatin . 21:30 23:45 2.25 13,302 13,333 PROD2 DRILL REAM T Wash and ream 8-1/2" hole. 23:45 00:00 0.25 13,333 13,365 PROD2 DRILL DDRL T Drilling. ECD's 9.3. 12/23/2006 00:00 06:00 6.00 13,365 13,591 PROD2 DRILL DDRL T Drilling. ECD's 9.3-9.4. Jar hrs 146.08 hrs. Av as 15 units. 06:00 12:00 6.00 13,591 14,113 PROD2 DRILL DDRL T Drilling. ECD's 9.4-9.55. Jar hours 149.66 hrs. Max as 180 units. 12:00 16:30 4.50 14,113 14,426 PROD2 DRILL DDRL T Drilling. ECD's 9.55- 9.81. Jar hours 151.94 hrs. Max as 116 units. 16:30 18:00 1.50 14,426 14,645 PROD2 DRILL DDRL P Drilling. ECD's 9.81-9.87. Jar hours 152.86 hrs. Max as 84 units. 18:00 00:00 6.00 14,645 14,948 PROD2 DRILL DDRL P Drilling. ECD's 9.887-9.8. Jar hours 155.46 hrs. Max as 56 units. 12/24/2006 00:00 06:00 6.00 14,948 15,134 PROD2 DRILL DDRL P Drilling. ECD's 9.80-9.84. Jar hours 158.51 hrs. Max as 34 units. 06:00 12:00 6.00 15,134 15,343 PROD2 DRILL DDRL P Drilling. ECD's 9.84-9.97. Jar hours 162.08 hrs. Max as 48 units. ___ ~ , _ ~ Pa~s~ ~t of ;ifs Time Logs_ _ _ _ __ ~ Date From To Dur S. Depth S~bcode T COM E. De th Phase Code 12/24/2006 12:00 14:30 2.50 15,343 _ 15,496 PROD2 _ DRILL DDRL P Drilling. ECD's 9.97-10.. Jar hours 163.36 hrs. Max as 95 units. 14:30 15:30 1.00 15,496 15,496 PROD2 DRILL CIRC P Circulate prior to POOH f/ geoPilot. Difficult in slidin . 15:30 16:30 1.00 15,496 14,556 PROD2 DRILL TRIP P POOH f/ geopilot and 6-3/4" bit du to difficulty in sliding. POOH w/ BHA #10, checkin LoTads, SLM.. 16:30 17:00 0.50 14,556 14,556 PROD2 DRILL OWFF P Monitor well. Pump dry job. Blow down to drive. 17:00 18:00 1.00 14,556 13,665 PROD2 DRILL TRIP P Continue POOH. Checking LoTads and su er sliders. SLM. 18:00 22:30 4.50 13,665 9,072 PROD2 DRILL TRIP P Continue POOH to above window. Checking LoTads and super sliders. SLM. 22:30 22:45 0.25 9,072 9,072 PROD2 DRILL OWFF P Monitor well @ window. Static. 22:45 23:15 0.50 9,072 9,072 PROD2 DRILL CIRC P Pump 25 bbls dry job (Dry job #2). Blow down top drive. Install air slips and stri er rubber. 23:15 00:00 0.75 9,072 8,072 PROD2 DRILL TRIP P Continue POOH. Checking LoTads and su er sliders. SLM. 12/25/2006 00:00 02:30 2.50 8,072 4,169 PROD2 DRILL TRIP P Continue POOH. SLM. 02:30 03:15 0.75 4,169 4,150 PROD2 DRILL PULD P Lay down Centurian circulating sub and crossovers. Change elevators to 4". Clear and clean ri floor. 03:15 03:30 0.25 4,150 4,150 PROD2 DRILL SFTY P Monitor well, static. PJSM on Laying down BHA. 03:30 05:00 1.50 4,150 1,800 PROD2 DRILL TRIP P POOH w/ 4" dp. SLM. 05:00 05:30 0.50 1,800 1,780 PROD2 DRILL PULD P Lay down shock sub and agitator and x-o's. 05:30 06:00 0.50 1,780 1,217 PROD2 DRILL TRIP P Continue POOH w/ BHA#10. SLM. 06:00 07:30 1.50 1,217 95 PROD2 DRILL TRIP P Continue POOH w/ BHA#10. SLM. 07:30 08:15 0.75 95 95 PROD2 DRILL OTHR P Download Sperry Sun MWD. 08:15 09:00 0.75 95 0 PROD2 DRILL PULD P Continue UD BHA#10. 09:00 09:30 0.50 0 0 PROD2 DRILL OTHR P Clear and clean rig floor. 09:30 10:45 1.25 0 85 PROD2 DRILL PULD P PU/MU BHA #11. 10:45 11:15 0.50 85 85 PROD2 DRILL OTHR P Upload Sperry Sun MWD. 11:15 12:00 0.75 85 650 PROD2 DRILL PULD P Continue MU BHA #11. 12:00 12:30 0.50 650 650 PROD2 DRILL OTHR P Shallow test MWD and Geopilot. Blow down to drive. 12:30 15:15 2.75 650 4,120 PROD2 DRILL TRIP P RIH w/ 4" dp and BHA #11. Fill pipe ever 20 stands. 15:15 15:30 0.25 4,120 4,144 PROD2 DRILL PULD P Change elevators to 5". MU Centurian circulatin valve and crossover. 15:30 18:00 2.50 4,144 8,902 PROD2 DRILL TRIP P RIH w/ BHA #11 on 5" dp. Fill every 20 stands. Record PU and SO wt's every 10 stands. ~~~ 43 of 5~ 1 Time Logs _ ---- _ Date From To Dur S, Depth E. De th Phase Code Subcode T COM _ _ _ _- _ 12/25/2006 18:00 19:00 1.00 _ 8,902 8,902 PROD2 RIGMN SVRG P _ Fill pipe. Service top drive. 19:00 00:00 5.00 8,902 13,332 PROD2 DRILL TRIP P Continue RIH w/ BHA #11 on 5" dp (44 stands slick, 35 stands w/super sliders, then 17 stands w/ Lotads. Filled pipe every 10 stands. Recorded PU and SO wt's every 5 stands. Observed no SO wt 13332'. 12/26/2006 00:00 01:30 1.50 13,332 13,438 PROD2 DRILL REAM P Ream and work hole transition f/ 8-1/2" x 6-3/4" 01:30 02:30 1.00 13,438 13,438 PROD2 DRILL REAM P Ream out of hole working transition f/ 13438' to 13243', then back down to 13438'. 02:30 02:45 0.25 13,438 13,470 PROD2 DRILL TRIP NP Trip in hole. 02:45 06:15 3.50 13,470 15,496 PROD2 DRILL REAM NP Ream in hole. 06:15 12:00 5.75 15,496 16,090 PROD2 DRILL DDRL P Drilling. ECD's 10.12-10.49 ppg. Jar hours 166.90 hrs. Max as 95 units. 12:00 18:00 6.00 16,090 16,491 PROD2 DRILL DDRL P Drilling. ECD's 10.34 - 10.5 ppg. Jar hours 170.67 hrs. Max as 110 units. 18:00 00:00 6.00 16,491 17,007 PROD2 DRILL DDRL P Drilling. ECD's 10.35- 10.41 ppg. Jar hours 174.42 hrs. Max as 94 units. 12!27/2006 00:00 03:15 3.25 17,007 17,233 PROD2 DRILL DDRL P Drilling. ECD's 10.41-10.45 ppg. Jar hours 176.81 hrs. Max as 121 units. 03:15 03:45 0.50 17,233 17,233 PROD2 DRILL SRVY P Survey and verify TD of "D" lateral @ 17233'. 03:45 05:15 1.50 17,233 17,233 PROD2 DRILL CIRC P Pump 35 bbls 10.6 ppg 130 vis sweep. Follow w/ circ @ 325 gpm w! 3400 psi. Rotate 140 rpm w/ 17k torque. PU 250k, SO 72K, Rot 148k. Recip f/ 17233' to 17135'. 05:15 05:30 0.25 17,233 17,233 PROD2 DRILL OTHR NP Break off single. Drop 2-1/8" steel ball to open Centurian circulating valve. Valve 13097'. 05:30 06:15 0.75 17,233 17,233 PROD2 DRILL CIRC NP With 2-1/8" ball dropping : Circ @ 28 spm (2.8 bpm, 118 gpm) w/ 740 psi. PU wt 248k, SO wt 70k, Rot wt 142k. Rotating 120 rpm w/ 17k ft Ib torque. Working pipe f/ 17233' to 17200'. Ball on seat @after 1366 strokes pumped 137 bbls . 06:15 06:30 0.25 17,233 17,233 PROD2 DRILL OTHR NP Pressure to 1400 psi, hold f/ a minute, increase to 1900 psi, hold f/ 30 seconds, increase to 2380 psi when valve shifted open allowing pressure to drop. Bleed pressure to zero. Pump @ 28 spm w/ 350 psi indicating valve o en. j F'an~: ~~ oaf J Time Logs Date From l o Dur _ S. Depth _ E De th _ - Phase - - Code Subcode T COM 12/27!2006 06:30 11:00 4.50 _ 17,233 17,233 _ PROD2 _T DRILL CIRC NP Circulate through Centurian circulating valve @ 13097'. Circulate and rotate 120 rpm w/ 16k ft Ib torque, recip 90'. PU wt w/ rotating 150k, SO wt w/rotating 120k. Pump one BU @ 550 gpm w/ 1870 psi. Then go to 650 gpm w/ 2430 psi till almost another bottoms, then go to 700 gpm w/ 2680 psi until another BU+, then try 750 gpm f/ a little while (appears hole might be taking a little fluid), drop back to 700 gpm w/ 2640 psi. Pump a total of 6 BU from circ sub (39352 strokes= 3951 bbls). Hole appears very clean @ shakers. Total fluid loss while circulating was 33 bbls. 11:00 12:00 1.00 17,173 17,173 PROD2 DRILL CIRC NP Drop 2-1/8" steel ball to close Centurian circulation valve. Pump @ 28 spm (2.8 bpm) w/ 310 psi. Ball on seat with 1590 strokes (159.6 bbls). Increase pressure to 1400 psi, hold f/ one minute. Increase pressure to 1900 psi, hold f/thirty seconds. Increase pressure to 2300 psi when valve shifted (pressure loss). Let pressure drop, then bleed off all pressure. Note: PJSM on displacing to solids free oil base mud held while ball was bein circulated down. 12:00 12:15 0.25 17,173 17,173 PROD2 DRILL CIRC NP Bring pumps to 28 spm w/ 340 psi. Bring pumps up to 324 gpm w/ 830 psi. Valve appears to be in open osition. 12:15 13:00 0.75 17,173 17,173 PROD2 DRILL CIRC NP Call vendor. Discuss situation. Prior to dropping another ball to activate tool, tried to circulate. String pressured up. Went through sequence again to shift tool. Went to 1400 psi, then 1900 psi, shifted @ 2300 psi. let pressure drop to 740 while then maintaining 28 spm w/ 800 si. Tool a ears to be shut. 13:00 13:30 0.50 17,173 17,233 PROD2 DRILL CIRC P Ream in hole. Rotate 120 rpm w/ 16-17k ft Ib torque. Pumping 77 spm 324 m) w/ 2950 si. 13:30 16:15 2.75 17;233 17,233 PROD2 DRILL CIRC P Displace 8.5 Oil Base mud from well with 8.7 ppg solids free Oil base mud.Reciprocate 30'. Pumping 320 gpm w/ 2740 psi. Rotate 120 rpm w/ 16-18k ft Ib torque. ECD's 10.25 ppg. PU wt 240k, SO wt 70k unless rotating. Pumped total of 1166 bbls to dis lace well. 16:15 16:30 0.25 17,233 17,233 PROD2 DRILL OWFF P Monitor well, static. 16:30 17:15 0.75 17,233 16,284 PROD2 DRILL TRIP P POOH on elevators. Pulling wet pipe. ~. ~ ~ ~.e_._~~e~___.~.~__ ~ .d ~ _____ p~rt~ ~~~+ a~f l Time Logs Date From To _ Dur S. De th E. Depth Phase Code Subcode T COM ~ _ __ 12/27/2006 17:15 18:00 0.75 16,284 16,284 PROD2 DRILL CIRC P Drop ball to actibvate Centurian circulating valve. With 2-1/8" ball dropping :Circ @ 29 spm (2.91 bpm, 122.3 gpm) w/ 530 psi. PU wt 240k, SO wt 70k unless rotating, Rot wt 135k. Rotating 120 rpm w/ 17k ft Ib torque. Working pipe f/ 16284' to 116224'. Ball on seat @ after 1305 strokes pumped (131 bbls). Increase pressure to 1500 psi and hold f/ a minute. Increase pressure to 2000 psi holding f/thirty seconds. Increased pressure and shifted valve @ 2350 psi. Pumped @ 28 spm w/ 160 psi-- Valve o ened. 18:00 00:00 6.00 16,284 6,618 PROD2 DRILL TRIP P Continue POOH w/ BHA #11. Recording PU and SO wt's every 5 stands in open hole, every 10 stands in casing. Monitor well on trip tank. Hole took 17 bbls over calculated on tri to this de th. 33 PROD2 DRILL DDRL P Drilling. ECD's 10.41-10.45 pp ar hours rs. ax 0 03:45 0.50 17,233 17,233 PROD2 DRILL SRVY P Survey and verify TD 'D" lateral @ 17233'. 03:45 05:1 1.50 17,233 17,233 PROD2 DRILL CIRC P Pump 35 b 10.6 ppg 130 vis sweep. Follo Circ @ 325 gpm w! 3400 '. otate 140 rpm w/ 17k torque. PU 250k, SO 72K, Rot 148k. Recip f/ 17233' to 17135'. 05:15 05:30 0.25 17,233 17, PROD2 DRILL O NP Break off single. Drop 2-1/8" steel ball to open Centurian circulating valve. Valve 13097'. 05:30 06:15 0.75 17,233 17,233 PRO LL CIRC NP With 2-1/8" ball dropping :Circ @ 28 spm (2.8 bpm, 118 gpm) w/ 740 psi. PU wt 248k, SO wt 70k, Rot wt 142k. Rotating 120 rpm w/ 17k ft Ib torque. orking pipe f/ 17233' to 17200'. Ball ` ~®~ on t @after 1366 strokes pumped ~ ~ 137 bb 06:15 06:30 0.25 17,233 17,233 PROD2 RILL OTHR NP Pressure to 1 si, hold f/ a minute, increase to 1900 p old f/ 30 seconds, increase to 23 si when valve shifted open allowing pr ure to drop. Bleed pressure to zero. Pump 28 spm w/ 350 psi indicating valve o en. l~agz: A ~ff ~t7 ~ __ .__ __._._____._ _ _ ___._._._ __. m___ _ .~~.______ ~ _ _ _~.__._... _ __ _ __~..._._.___ ~ _____,I Time Lags _ -- - - Date From To Dur S, Depth E. De~th Phase _ Code _ Subcode T COM __ ! 12/27/2006 06:30 _ 11:00 4.50 _ 17,233 _ 17,233 PROD2 DRILL CIRC NP __ _ Circulate through Centuria -circulating valve @ 13097'. Circulat and rotate 120 rpm w/ 16k ft Ib for e, recip 90'. PU wt w/ rotating 150 , SO wt w/rotating 120k. P pone BU @ 550 gpm w/ 1870 psi. en go to 650 gpm wJ 2430 psi till ost another bottoms, then o to 700 gpm w/ 2680 psi until ano er BU+, then try 750 gpm f/ a li a while (appears hole might be aking a little fluid), drop back t 00 gpm w/ 2640 psi. Pump a total f 6 BU from circ sub (39352 str es= 3951 bbls). Hole appears v ry clean @ shakers. Total fluid loss hile circulatn was 33 bbls. 11:00 12:00 1.00 7,173 17,173 PROD2 DRILL CIRC N Drop 2-1/8" steel ball to close /~ Centurian circulation valve. Pump @ 28 spm (2.8 bpm) w/ 310 psi. Ball on seat with 1590 strokes (159.6 bbls). ~ Increase pressure to 1400 psi, hold f/ t one minute. Increase pressure to 1900 ~ psi, hold f/ thirty seconds. Increase pressure to 2300 psi when valve shifted (pressure loss). Let pressure drop, then bleed off all pressure. Note: PJSM on displacing to solids free oil base mud held while ball was bein circulated down. 12:00 12:15 0.25 17,173 17,173 PROD RILL CIRC NP Bring pumps to 28 spm w/ 340 psi. Bring pumps up to 324 gpm w/ 830 psi. Valve appears to be in open osition. 12:15 13:00 0.75 17,173 17,173 ROD2 DRILL C NP Call vendor. Discuss situation. Prior to dropping another ball to activate tool, tried to circulate. String pressured up. Went through sequence again to shift tool. Went to 1400 psi, then 1900 psi, shifted @ 2300 psi. let pressure drop 0 740 while then maintaining 28 spm 800 si. Tool a ears to be shut. 13:00 13:30 0.50 17, 3 17,233 PROD2 DRILL CIRC P Re in hole. Rotate 120 rpm w/ 16-17 Ib torque. Pumping 77 spm (324 w/ 2950 si. 13:30 16:15 2.75 17,233 17,233 PROD2 DRILL CIRC P Displace 8. Oil Base mud from well with 8.7 ppg lids free Oil base mud.Reciproca 30'. Pumping 320 gpm w/ 2740 psi. otate 120 rpm w/ 16-18k ft Ib torque. D's 10.25 ppg. PU wt 240k, SO wt 70 unless rotating. Pumped total 0 166 bbls to dis lace well. 16:15 1 :30 0.25 17,233 17,233 PROD2 DRILL OWFF P Monitor well, static. 16:3 17:15 0.75 17,233 16,284 PROD2 DRILL TRIP P POOH on elevators. Pulling wet p e. ~~~~ ~b ~~ ~~ f ~--- Time Lo s ~ - Date _ From To Dur S. De th E. De~t_h Phase Code Subcode T COM 7/2006 17:15 18:00 0.75 16,284 16,284 PROD2 DRILL CIRC P Drop ball to actibvate Centurian circulating valve. With 2-1/8" ball dropping : Circ @ 29 spm (2.91 bpm, 122.3 gpm) w/ 530 psi. PU wt 240k, SO wt 70k unless rotating, Ro ~ 135k. Rotating 120 rp k ft Ib ~ torque. Workin a f/ 16284' to ^~ ~ +~~ 11622 ' on seat @ after 1305 es pumped (131 bbls). Increase pressure to 1500 psi and hold f/ a minute. Increase pressure to 2000 psi holding f/ thirty seconds. Increased essure and shifted valve @ 2350 psi. Pum 28 spm w/ 160 psi-- Valve o ened. 18:00 00:00 6. 16,284 6,618 PROD2 DRILL TRIP P Continue POOH w #11. Recording PU and SO wt's 5 stands in open hole, every 10 stan in casing. Monitor well on trip tank. Hole took 17 bbls over calculated on tri to this de th. 12/28/2006 00:00 06:00 6.00 6,618 375 PROD2 DRILL TRIP P Continue POOH w/ BHA #11. Recording PU and SO wt's every 10 stands in casing. Monitor well on trip tank. Hole took 17 bbls over calculated on tri to this de th. 06:00 06:30 0.50 375 85 PROD2 DRILL TRIP P Monitor well @ BHA, POOH 4" HWDP and jars, rack in derrick. UD Flex drill collars. 06:30 07:30 1.00 85 85 PROD2 DRILL OTHR P Download Sperry Sun MWD. 07:30 08:30 1.00 85 0 PROD2 DRILL PULD P Lay down BHA #11.Break bit. Hole took 34 bbls over calculated f/trip out of hole. 08:30 09:30 1.00 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. Remove bits and subs. Rig down skate extension. Change elevators to 5". Monitor hole f/ losses. 09:30 09:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on cutting the drilling line. 09:45 11:15 1.50 0 0 COMPZ RIGMN SVRG P Slip and cut 129' of 1-3/8" drilling line. 11:15 12:00 0.75 0 0 COMPZ CASIN( OTHR P Move one row of 5"drill pipe w/super sliders to off driller's side pipe rack to avoid pinch point while PU liner from i e shed. 12:00 13:30 1.50 0 0 COMPZ CASINC RURD P Rig up equipment to run 4-1/2" x 5-1 /2"slotted/blank liner f/ "D" lateral. 13:30 14:00 0.50 0 0 COMPZ CASIN( SFTY P PJSM on running liner. 14:00 14:30 0.50 0 0 COMPZ RIGMN SVRG P Service top drive and lubricate rig. 14:30 15:30 1.00 0 0 COMPZ RIGMN OTHR P Derrick inspection. _ __ ~~ ~ _ ~~ ~~ ~ ~~~~ ~~ f 5~ n Time Logs Date From To Dur S. De th E Depth Phase Code Subcode T COM 12/28/2006 _ 15:30 18:00 2.50 _ 0 2,610 COMPZ CASIN( RNCS P MU/RIH w/ 3-1/2" shoe, 3-1/2" 9.3 ppf eue shoe jt, x-o, x-o, 4-1/2" 11.6 ppf BTC blanks and slotted liner. 60 jts of 4-1/2" in hole. Record PU and SO wt's eve 10 'ts. 18:00 19:30 1.50 2,610 4,274 COMPZ CASIN( RNCS P Crew change. Continue PU/MU 4-1/2" 11.6 ppf BTC liner (jt # 97 in hole), x-o, 3 jts of 5-1/2" 15.5 ppf BTC. (3 jts of 5-1/2" in the hole, 't # 100 in the hole 19:30 21:15 1.75 4,274 4,274 COMPZ CASIN( OTHR P PU 5-1/2" hydroform centralizers to the floor. Lay down 4-1/2" handling tools.Change out GBR tongs. PJSM on removing Sperry Sun tools from pipe shed. Remove tools from pipe shed. Post safety meeting on removin tools from i e shed. 21:15 23:30 2.25 4,274 6,851 COMPZ CASIN( RNCS P Continue PU/MU 5-1/2" 15.5 ppf BTC slotted/blank liner. Jt # 162 in the hole. 23:30 00:00 0.50 6,851 7,225 COMPZ CASIN( RNCS P Install 5-1/2" 15.5 ppf BTC x 15.5 ppf Hydril 521 x-o. Continue PU/MU 5-1/2" slotted/blank liner. Jt # 171 in the hole. Note: Hole taking approx 2bph throw hout the da . 12/29/2006 00:00 00:45 0.75 7,225 7,914 COMPZ CASIN( RNCS P Continue PU/MU 5-1/2" slotted/blank liner. Run Jt # 172 to jt # 188. Recording PU and SO wt's every 10 jts. Note: Hole taking approx 2bph throw hout the da . 00:45 01:30 0.75 7,914 7,941 COMPZ CASIN( RUNL P MU Baker 7" "HR"liner running tool w/ crossovers f/ 5-1/2" hydril 521 liner top and 4-1 /2" handling running tools on top (5" dp). Lay down GBR tongs. Clear and clean ri floor. 01:30 01:45 0.25 7,941 7,941 COMPZ CASIN< RUNL P MU a stand of drill pipe. While rotating 30 rpm: PU wt 120k, SO wt 115k, rotating wt 118k. Torque 4000 ft Ib. Pum in 31 s m with 150 si. 01:45 06:00 4.25 7,941 12,740 COMPZ CASIN( RUNL P Run liner in the hole on 5" drill pipe. Inspecting super sliders w/super slider rep. Recording PU, SO, rotating wt's and rotating torque every 10 stands. Filling pipe every 10 stands. Note: 5" string to run liner will be 4 stands slick, 35 stands w/super sliders, 40 stands with LoTads, then 17 stands slick. ~ - ~_ __ ~ ~'~~ ~9 cif 6 Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM _ 12/29/2006 06:00 12:30 6.50 12,740 17,224 COMPZ CASINO RUNL P Continue running liner in the hole on 5" drill pipe. Recording PU, SO, rotating wt's and rotating torque every 10 stands. Filling pipe every 10 stands. Started rotating liner/string @ 12740'. Rotating w/ 30 rpm. Watching and recording torque. Tag bottom of hole @ 17233'. PU and put liner on depth, with shoe @ 17224', top of liner to be 9294.57'. 12:30 13:30 1.00 17,224 17,224 COMPZ CASIN( CIRC P Drop 3/4" ball. Circ ball to seat um in 4 b m w/ 430 si. 13:30 13:45 0.25 17,224 9,295 COMPZ CASIN( OTHR P Ball on seat after pumping 168.4 bbls. Pressure to 3000 psi. Continue to pressure to 4300 psi to release f/ liner. PU wt 215k, SO wt 100k after releasin f/ runnin tool. 13:45 14:15 0.50 9,295 9,060 COMPZ DRILL TRIP P Lay down single in the pipe shed. POOH to Circ @ the slot of the whi stock 9060'. 14:15 15:00 0.75 9,060 9,060 COMPZ DRILL CIRC P Circulate bottom's up while washing slot of whipstock. Circulate @ 430 m w/ 1130 si. Circulated 500 bbls. 15:00 15:15 0.25 9,060 9,060 COMPZ DRILL OWFF P Monitor well. Static. 15:15 18:00 2.75 9,060 4,005 COMPZ DRILL TRIP P POOH w/ Baker running tools. Inspecting LoTads and super sliders. Note: Removed Sperry Sun GeoPilot skid from the ri floor while tri in . 18:00 20:30 2.50 4,005 25 COMPZ DRILL TRIP P Continue to POOH w/ Baker running tools f/ "D" lateral liner. Cleanin its. 20:30 21:00 0.50 25 0 COMPZ DRILL PULD P Lay down Baker 7" "HR" liner setting sleeve and inner strin .Cleanin its. 21:00 21:30 0.50 0 0 COMPZ DRILL OTHR P Rig up to lay down 4"drill pipe. Pull mouse hole, drain in pipe shed. Install mousehole in rotary table. Gather up 4" thread rotectors to the ri floor. 21:30 21:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down 4" drill pipe from the derrick using mousehole in rotary table. 21:45 00:00 2.25 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" dp f/ derrick. 12/30/2006 00:00 02:15 2.25 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" dp f/ derrick. 02:15 03:45 1.50 0 0 COMPZ DRILL OTHR P Change elevators to 5". Transfer some 5" dp to off driller's side of derrick. Remove mousehole from rotary table. Bring tools to rig floor for BHA #12. Weekly function test of choke and kill HCR, blinds, upper and lower pipe rams and annular. 03:45 04:00 0.25 0 0 COMPZ FISH SFTY P Pre job safety meeting on PU/MU BHA # 12 retrieve whi stock . 04:00 04:45 0.75 0 245 COMPZ FISH PULD P PU/MU BHA #12 (Whipstock retrieval assembl .Cleanin its. J Time Logs _ i_Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/30/2006 04:45 06:00 1.25 245 2,100 COMPZ FISH TRIP P Trip in hole w/ BHA #12 to retrieve whipstock. Fill ever 20 stands. Record PU and SO wt's eve 10 stands. 06:00 10:30 4.50 2,100 9,053 COMPZ FISH TRIP P Continue trip in hole w/ BHA #12 to retrieve whipstock. Fill ever 20 stands. Record PU and SO wt's every 10 stands. 10:30 10:45 0.25 9,053 9,053 COMPZ FISH CIRC P Fill pipe and circulate. 10:45 11:00 0.25 9,053 9,178 COMPZ FISH FISH P Finish RIH locate slot @ 9091' w/ hook, PU to 50k over, 60k, 70k, 80k over when anchor released. Pull up hole 30'. Hole took 31 bbls of fluid when ulled free. 11:00 12:30 1.50 9,178 9,178 COMPZ FISH CIRC P Circulate bottom's up. Pumping 340 gpm w/ 1460 psi. Losing 1 bpm. Slowed rate to 5 bpm w/ 580 psi. Losing .5 bpm. Max gas 14 units. Lost total of 54 bbls fluid while circulatin . 12:30 12:45 0.25 9,178 9,178 COMPZ FISH OTHR P Observe well for flow. Static. 12:45 13:00 0.25 9,178 9,178 COMPZ FISH OTHR P Install stripping rubber, air slips, blow down to drive. 13:00 18:00 5.00 9,178 501 COMPZ FISH TRIP P POOH carefully w/ Window master slide assembly (117.71') and fishing BHA #12. 18:00 20:15 2.25 501 0 COMPZ FISH TRIP P Crew change. Continue POOH carefully w/ Window master slide assembly (117.71') and fishing BHA #12. Lay down all. Lost 31 bbls of fluid while POOH w/ whipstock. Slide looked real) ood. 20:15 20:45 0.50 0 0 COMPZ FISH PULD P UD Baker tools. Clear and clean rig floor. 20:45 22:00 1.25 0 0 COMPZ RPCOh RURD P PU and RU tools to run Baker PZ Hook Han er f/ Plo and dro s stem. 22:00 22:15 0.25 0 0 COMPZ RPCOA SFTY P Pre job safety meeting for running Hook han er assembl . 22:15 23:15 1.00 0 233 COMPZ RPCOR RCST P PU/MU Hook hanger assembly. 23:15 00:00 0.75 233 233 COMPZ RPCOh RCST P Rig up to run inner string. Making up inner string. Note: Total fluid losses f/ the day = 137.5 bbls. Static losses a rox 1-1/2 b h. 12/31/2006 00:00 00:30 0.50 233 233 COMPZ RPCOh OTHR P Making up inner string. MU inner strip to hook han er. 00:30 01:15 0.75 233 270 COMPZ RPCOh OTHR P Making up inner string, including Sperry sun MWD super slim 3-1/8". Orient to hook. Lower hook hanger to floor. 01:15 02:00 0.75 270 270 COMPZ RPCOh RURD P Rig down GBR and Baker tools. Lay down same. Clear and clean floor. I'~xge ~a~ e~I iii"r l J Time Lo s ~ . _ ___ __ --- _ Date From To fur S Depth E. De th Phase Code Subcode T COM _ 12/31/2006 02:00 _ 02:30 0.50 270 360 COMPZ RPCOh OTHR P ______ RIH with Baker PZ Plop and drop hook hanger on a stand of 5" drill pipe. Shallow test Sperry Sun super slim tools. Pumping 120 gpm w/ 560 psi, 5% flow. PU wt 80k, SO wt 80k. Blow down to drive. 02:30 06:00 3.50 360 6,550 COMPZ RPCOh TRIP P RIH w/ PZ hook hanger assembly on 5"drill pipe. Record PU and SO wt's eve 10 stands. 06:00 08:00 2.00 6,550 9,303 COMPZ RPCOh TRIP P Continue RIH w/ PZ hook hanger assembly on 5"drill pipe. Record PU and SO wt's eve 10 stands. 08:00 08:45 0.75 9,303 9,317 COMPZ RPCOR TRIP P Tagged up @ 9303' in main/mother wellbore--??. POOH to 9077' (above window: TOW @ 9084', BOW @ 9100'). MU top drive. Orient Hook w/ MWD while circulating 118 gpm w/ 700 psi. RIH to 9317', going out window 9084' -9100') into o en hole. 08:45 10:30 1.75 9,317 9,347 COMPZ RPCO11 TRIP P POOH to re-orient to hook bottom of window @ 9104' MD (approx 4' deep). PU wt 205k, SO wt 105k, blocks 70k. 10:30 11:15 0.75 9,347 9,347 COMPZ RPCOh OTHR P Hooked bottom of window with hook @ 9104' w/ tail (mule shoe of bent jt) @ 9347'. MWD indicating 12 right after hooked w/ 30k slack off. PU 25', turn 180 deg, work string 8' past window, Pick hook back up above window. Re orient and set hook on window @ 9104' w/end of bent joint @ 9347' inside of Plop and drop "D" lateral liner. MWD indicated 10 right w/ 30k on hook han er. 11:15 12:15 1.00 9,347 9,347 COMPZ RPCOR PACK P Drop 1-3/4" ball, circ ball down 1200 strokes @ 124 gpm w/ 760 psi, then slow to 84 gpm w/ 800 psi, ball on seat @ 1310 strokes. Pressure to 2000 psi, held f/ a minute, pressure to 2800 psi to open and inflate ECP (Hook hanger assembly was pinned to release with 2065 psi) pressure bleed down to 1250 psi. Took 9 strokes to pressure back up to 2800 psi. Inflated ECP w/ .904 bbls (38 gals) 8.7 ppg solids free oil base mud. 12:15 18:00 5.75 9,347 1,600 COMPZ RPCOh TRIP P POOH w/ Baker hook hanger running tools and inner string w/ Sperry Sun su er slim MWD. 18:00 19:30 1.50 1,600 185 COMPZ RPCO(` TRIP P Continue POOH w! Baker hook hanger running tools and inner string w/ S er Sun su er slim MWD. 19:30 20:45 1.25 185 0 COMPZ RPCOh PULD P Lay down Baker running tools and 2-3/8" inner string and Sperry Sun su er slim 3-1/8" MWD. 20:45 21:45 1.00 0 0 COMPZ RPCOM1 OTHR P Clear and clean floor. RD tools f/ hook hanger. RU to run Baker LEM f/ Plop and dro . __ 4~~~e ~? r~~ 5 e C~ ;~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM _ j 12/31/2006 21:45 __ 22:00 0.25 0 0 COMPZ RPCOh SFTY P ___ PJSM on PU/MU Baker4-1 /2" LEM assembl . 22:00 23:00 1.00 0 195 COMPZ RPCOh RCST P PU/MU 4-1 /2" Baker LEM assembly for to and dro . 23:00 23:15 0.25 195 195 COMPZ RPCOh OTHR P Change elevators to 5". 23:15 23:45 0.50 195 195 COMPZ RPCOh PULD P PU 9-5l8" x 7" Baker ZXP w/ running tool. MU inner string w/ Sperry Sun 3-1/2"super slim MWD oriented to the bottom oint of LEM o enin of LEM . 23:45 00:00 0.25 195 227 COMPZ RPCOh RCST P MU 9-5/8" x 7" ZXP w/ running tool and inner string. Note: Total fluid lost to hole toda = 36 bbls 01/01/2007 00:00 01:15 1.25 227 227 COMPZ RPCOh RURD P Rig down equjpment to run LEM f/ the "D" lateral 1J-136L1 . Clear ri floor. 01:15 01:30 0.25 227 320 COMPZ RPCOh TRIP P RIH w/ LEM assembly on one stand of 5"drill pipe. Shallow test Sperry Sun MWD tool. Pump 120 gpm w/ 500 psi. O K. 01:30 06:00 4.50 320 6,309 COMPZ RPCOh TRIP P Trip in hole w/ LEM on 5" drill pipe. Record PU and SO wt's every 10 stands. Run 90 ft/min max. Fill pipe eve 20 stands. 06:00 09:00 3.00 6,309 9,226 COMPZ RPCOh TRIP P Continue RIH w/ LEM after crew change. Ran LEM on 4 stands of 5" dp slick, 35 stands w/super sliders, 40 stands w/ LoTads, then 14 slick 5"d . 09:00 09:30 0.50 9,226 9,226 COMPZ RPCOh CIRC P PU a single from the pipe shed. Circulate and orient Lem. PU wt 205k, SO wt 105k. 09:30 10:30 1.00 9,226 9,240 COMPZ RPCOh PACK P RIH to 9240'. Latch LEM. Sperry Sun MWD indicating 4 deg left w/ 30k down. Pull to 240k snapped out. Set back down 30k to latch. Drop ball. Circulate ball to seat w/ 3 bpm. Ball on seat @ 1140 strokes. Presssure to 2800 psi. Set ZXP packer, continue to pressure to 4000 psi to release running tool f/ LEM assembly. Top of ZXP 9018.78'. 10:30 10:45 0.25 9,240 9,063 COMPZ RPCOh DHEQ P Rig up and test 7" x 9-5/8" "SLZXP" Liner top packer to 1000 psi f/ 5 min. Chart test OK. 10:45 11:30 0.75 9,063 7,893 COMPZ RPCOti TRIP P Pull out of hole with LEM running tools and 5" d . 11:30 12:00 0.50 7,893 7,893 COMPZ RPCOh OTHR P Blow down top drive and kill line. Install stripper rubbers after monitoring well. Static. 12:00 15:30 3.50 7,893 225 COMPZ RPCOh TRIP P Crew change. Continue POOH w/ LEM runnin tools. 15:30 16:30 1.00 225 0 COMPZ RPCOh PULD P Lay down LEM running tools, inner string w/ Sperry Sun 3-1/8" super slim MWD. 16:30 17:00 0.50 0 0 COMPZ RPCOR OTHR P Pull Vetco Gray 12-3/8" ID wear bushin . _ ~- r____W_ ~ __.~ _ i ~~ ~ ~ ~~ • • Time Logs bate FromTo_ Dur _ S. Depth__E, De th Phase Code Subcode T___COM _ _ 01/01/2007 17:00 17:30 0.50 0 0 COMPZ RPCOh PULD P Rig down toots f/ LEM, Clear and clean ri floor. 17:30 18:45 1.25 0 0 COMPZ RPCOh RURD P RU to run 4-1/2" completion. 18:45 19:15 0.50 0 0 COMPZ RPCOh SFTY P PJSM on running 4-1/2" completion. 19:15 20:15 1.00 0 0 COMPZ RPCOh OTHR T Change out 4-1/2" tubing tongs. An "O" ring on the shaft of the throttle control was cut/damaged. Rig up backu ton s. 20:15 00:00 3.75 0 4,023 COMPZ RPCOh RCST P Run 4-1/2" 12.6 ppf L-80 IBT-mod completion per running order. Jt # 130 in hole midni ht. 01/02/2007 00:00 06:00 6.00 4,023 9,060 COMPZ RPCOh RCST P Run 4-1/2" 12.6 ppf L-80 IBT-mod completion per running order. Run from 4023' - 9060' MD. Ran 291 joints, tagged up 15' in on joint # 292. Crew Chan e 06:00 07:30 1.50 9,060 9,060 COMPZ RPCOh RCST P POOH lay down 5jnts 4 1/2" tubing. Pick up 3 joints for space out as per BOT re & Co. Man. 07:30 08:00 0.50 9,060 9,060 COMPZ RPCOh RCST P Make up tubing hanger. Install BPV. Make u landin 'oint. 08:00 09:30 1.50 9,060 9,060 COMPZ RPCOh HOSO NP Attempt to land tubing hanger. Observed landing high. Pull to floor & inspect same. Attempt to land. No go. Pull up 4'. Heat well head with steam. Land tubing hanger in correct position as per Vetco Gray rep. RILDS. SIMOPS: Cleaning pits, change out piston rubbers, liners & seats in mud um s. and valves on #2. 09:30 10:00 0.50 9,060 0 COMPZ RPCOh RCST P Back out & pull landing joint. Rig down all tubin runnin a ui ment. 10:00 10:15 0.25 0 0 COMPZ RPCOR OTHR P Rig up and test upper & lower hanger seals to 5000 PSI. Hold for 10 minutes each. 10:15 10:45 0.50 0 0 COMPZ RPCOh OTHR P Pull Mouse hole. Install in rotary table for la in down DP from derrick. 10:45 12:00 1.25 0 0 COMPZ RPCOII OTHR P Held PJSM with crew. Discuss safety issues and procedure for laying down DP from derrick. Discuss removal procedures for LoTads & Super Sliders. Begin lay down DP from derrick. 12:00 18:00 6.00 0 0 COMPZ RPCOh OTHR P Continue break out & lay down drill pipe from derrick, removing Lotads & super sliders. Note: Sliders froze to DP. needed to use steam to thaw out sliders for removal. 1NWf Reps on rig floor. Crew Chan e e~_ ~ ~. _ . ~~ ~~ ~'a~~ a ~~ 5~s 5 • '~ Tune 1_ogs - __ Date From To Dur S. De th E. De th" '.Phase Code Subcode T --- COM 01/02/2007 18:00 00:00 6.00 0 0 COMPZ RPCOh _ OTHR P ____ Continue break out & lay down drill pipe from derrick, removing Lotads & super sliders. Note: Sliders froze to DP. needed to use steam to thaw out sliders for removal. WWT Reps on rig floor. SIMOPS: Continue clean pits and prepare for rig move. purge all lines from SFMOBM. 01/03/2007 00:00 06:00 6.00 0 0 COMPZ RPCOA OTHR P Continue break out & lay down drill pipe from derrick, removing Lotads & super sliders. Note: Sliders froze to DP. needed to use steam to thaw out sliders for removal. WWT Reps on rig floor. Crew Chan e 06:00 11:30 5.50 0 0 COMPZ RPCOh OTHR P Continue break out & lay down drill pipe from derrick. SIMOPS: Remove suction line from Mud pup #1 -repair same. Install new guides for suction screen on #1 pump, suction pod. re are rockwasher for ri move. 11:30 12:00 0.50 0 0 COMPZ RPCOII RURD P Remove mousehole from rotary tale & lay down same. Clean & clear floor area of all thread protectors, lift subs, su er sliders and clam s. 12:00 12:15 0.25 0 0 COMPZ WELCT SFTY P Held PJSM with crew. Discuss safety issues and procedure for nipple up and down BOP stack & tree. 12:15 14:00 1.75 0 0 COMPZ WELCT NUND P Nipple down BOP stack & lines. Remove all drill pipe from pipe shed. Blow down & Ri down all mud lines. 14:00 16:00 2.00 0 0 COMPZ WELCT NUND P Nipple up Tree as per Vetco Gray re s. 16:00 17:00 1.00 0 0 COMPZ RPCOA FRZP P PJSM with rig crew & Little Red Services. Discuss safety issues, rigging up and pumping freeze protect diesel. Rig up all flanges and lines. test lines to 1000 PSI. Spot & rig up vac trucks and lines. Designate a Spill cham ion. 17:00 18:00 1.00 0 0 COMPZ RPCOh FRZP P Pump down annulus taking returns through tubing and through the choke mainfiold with little Red. Pumping @ 4 BPM -average 500 PSI. monitoring fluid loss. No loss at 4 BPM. Crew Chan e 18:00 20:45 2.75 0 0 COMPZ RPCOh FRZP P Continue pump down annulus taking returns through tubing and through the choke mainfiold with little Red. Pumping @ 4 BPM -average 500 PSI. Observe pumping a total of 675 BBLS of diesel to get good diesel returns. Total of 660 BBLS returned. Loss = 15 BBLS. 20:45 21:00 0.25 0 0 COMPZ RPCOh FRZP P Shutdown Little Red. Shut in well. FCP = 300 PSI. _ _r_~~ ~ct~ 55 cif ~~ • • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM - - 01/03/2007 21:00 21:30 0.50 0 0 COMPZ RPCOh FRZP P Blow down Choke line. Suck out lines to Little Red. Rig down Little Red & Vac trucks. 21:30 22:00 0.50 0 0 COMPZ RPCOA OTHR P Rig Up Vetco Gray lubricator with BPV. Install Lubricator & set BPV as per Vetco Gray reps. RD Lubricator. Shut in and secure well. Install blanking flanges. Shut in pressures = Tubing = 150 PSI. IA = 200 PSI. OA = 150 PSI. 22:00 00:00 2.00 0 0 COMPZ MOVE DMOB P Continue clean pits and rig down cellar lines. Clean drip pan. Clean out cellar box. Wipe down tree. Rig Released 2400 HRS. ®m~ ~®_ ~~~~ ~~ ufi ~~ I 1J-136 PB and 1J-136 L1 (PTD #'s 206-154, and 206-155 respectively) ~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, January 23, 2007 3:31 PM To: Thomas E Maunder Cc: NSK Prod Engr Tech; NSK West Sak Prod Engr Subject: 1J-136 PB and 1J-136 L1 (PTD #'s 206-154, and 206-155 respectively) Tom, CPAI would like to give notice of intent to producing 1J-136 PB and 1J-136 L1 (PTD #'s 206-154, and 206-155 respectively). The well will be produced by gas lift down the IA and through the sliding sleeve for a period of approximately 30 days. The well was designed and drilled to be a pre produced injector. After the production clean up phase, the appropriate paperwork will be submitted to change its service status to injector. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 7/3/200'7 C.~~-_ ~C~tl~mf~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~.~f I ~ r" t>~i~~l,,+~ ~~ -l S'~/ Log Description NO. 4092 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD ovo2/o~ 2N-304 11416232 FBHP SURVEY 10130/06 1 2N-304 11296737 FBHP SURVEY 11/04106 1 1D-109 N/A INJECTION PROFILE 11127106 1 1J-136 (REDO) 11534188 USIT 12/10106 1 1R-18 NIA SBHP/DD 12118/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 1D-103 11548555 _ INJECTION PROFILE 12/20/06 1 3K-09A NIA SBHP SURVEY 12/22/06 1 3K-26 NIA SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23106 1 2N-326 11551840 SBHP SURVEY 12/24106 1 3S-19 11548564 PRODUCTION PROFILE 12125106 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26106 1 2A-20 11548565 INJECTION PROFILE 12126/06 1 2M-15 11551843 PRODUCTION PROFILE 12127/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12130106 1 • Please sign and return one copy of this transmittal to Seth at the above address or fax to (907) 561-8317. Thank you. ,` r 12/19/06 NO. 4077 Schlumberger -DCS ~ ~ ~ ~~ ~L~~~ 2525 Gambell Street, Suite 400 .e ., .~~,® ~ Y~~~y~~ ¢sIE:,~ Company: Alaska Oil & Gas Cons Comm Anchora e, AK 99503-2838 ' ~ ~I>"~° g Attn: Christine Mahnken ATTN: Beth Ord ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~~~ ~ ~~~ Field: Kuparuk Well Job # Log Description Date BL Color CD 1R-03A (REDO 11483497 INJECTION PROFILE 11/30/06 1 1B-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-08B 11538771 PRODUCTION PROFILE 12/12/06 1 3H-10B 11534187 PRODUCTION PROFILE 12/08/06 1 1J-136 11534188 USIT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1 F-10 11534192 INJECTION PROFILE 12/12/06 1 1Y-27 N/A PRODUCTION PROFILE 12/14/06 1 2Z-20 N/A SBHP SURVEY 12/15/06 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 1F-05 N/A INJECTION PROFILE 12/13/06 1 1 F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1H-14 11551835 SBHP SURVEY 12/18/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Re: IJ-136 (206-154) sidetrack ~ ~ Subject: Re: 1J-136 (206-154) sidetrack From: Thomas M~.under <tom maunder~a?,admin.state.ak.us> Date: Thu, 30 Nov 2006 07:42:47 -0900 'I'o: "Nugent, David ~lrnoid" <David.A.Nuotntrc~lcc~nocophillips.com> David, Your message is acknowledged. Based on the information I have this lost section should be isolated since the TOC of your cement job is planned well above the sidetrack point. Nothing further is needed. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 11/30/2006 7:12 AM: Tom, We experimented with drilling our intermediate hole with a two cone bit. It did real well until we ran one of the cones off the bit about 900' before intermediate casing point. We did a low side open hole sidetrack and went around the cone in the hole (we used a tri cone bit this time) and got past the cone successfully. We abandoned about 158' of hole. None of our targets have changed. Sidetrack PB1 • Well: 1 J-136 • Rig: Doyon 15 • Permit #: 206-1:54 • Date: November 29, 2006 • Time: 0700 hours • Last casing: 13-3/8" at 3501' • MD of abandoned section: 8700' - 8858' If you have any questions, please contact me. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska 907-265-6862 (office) 918-662-6886 (fax) 1 of 1 11/30/2006 8:26 AM 1J-136 Spud Timing Update (Probably Tuesday or Wednesday) • subject: 1J-136 Spud Timing Update (Probably Tuesday or Wednesday) From: "Reilly, Patricl~ J" <Patriek.J.Reilly@conocophillips.corrz> Date: Thu, 09 Nov 2006 08:56:16 -0900 To: Thomas Maunder < onl_ maundcr(ci;admin.state.ak.us=- CC: "nilsup-Drake, Sharon K" <Sharon.K.Allsup-Di-ake~ci?conocophillips.com==- Tom,. If all goes well or~/1J-182, Pat Reilly ConocoPhillips Ala k~ Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly@conocophillips.com «Patrick.J.Reilly@conocophillips.com.vcf» should be moving 1J-136 on esday or Wednesday. 1 of 1 11/9/2006 12:37 PM Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-136 ConocoPhillips (Alaska), Inc. Permit No: 206-154 Surface Location: 1565' FSL, 2282' FEL, Sec. 35, T11N, R10E, UM Bottomhole Location: 1772' FSL, 441' FEL, Sec. 14, TlON, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90759-3607 (pager). DATED this day of November, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMI ION ~ ~ z00 fj PERMIT TO DRILL `~~`~ 20 AAC 25.005 1~~~~ C~~ & fas Cons. Commission 1a. Type of Work: 1b. Current Well Class: Exploratory Development Oil ^ 1c. Specify if well is pr Drill ^/ Re-drill ^ Stratigraphic Test ^ Service Q Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-136 3. Address: 6. Proposed Depth: 12. FieldlPool(S): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 17408' ~ TVD: 3436' • Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surtace: 1565' FSL, 2282' FEL, Sec. 35, T11 N, R10E, UM ~ ADL 25662 & 380058 West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 875' FNL, 412' FEL, Sec. 11, T10N, R10E, UM ALK 2177 & 4604 11/13/2006 Total Depth: 9. Acres in Property: 14. Distance to lt~.i p~, 1772' FSL, 441' FEL, Sec. 14, T10N, R10E, UM 2560 Nearest Property: > ~+' /• 9• 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest ~ e Z Surface: x- 558931 y- 5945378 ~ Zone- 4 (Height above GL): 40' RKB feet Well within Pool: 1J-102L1 ,~ 16. Deviated wells: Kickoff depth: 400 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) i~' Maximum Hole Angle: 91 ° deg Downhole: 1611 psig Surface: 1217 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 120' 120' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3549' 40' 40' 3589' ~ 2197' • 680 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9506' 40' 40' 9546'• 3573' - 630 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 7862' 9546' 3573' 17408' . 3436' slotted liner 19 PRESENT WELL CONDITION SUMMARY (TO be completed for Redrill and Re-Entry Operations) Total Depth MD (tt): Total Depth TVD (tt): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch ^ Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature` ~ ~`, ~"` ~ ~--~ ` Phone ~ ~ S ~ ~' j~, Date ((~ 15 /a ~, °-+.~. _ --~ Pr h n D k Commission Use Only Permit to Drill API Number: Permit Approva See cover letter Number: ~~ - ~s' 50- ~`/ ^ 2333 /~ a5 Date: ~ for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbedrmvethane, gas hydrates, or gas contained in shales: ~j~ P~ ~~~ ~~ ~~ ~~~ Samples req'd: Yes ^ No I~ Mud log req'd: Yes ^ No [~ Other: t~ H2S measures: Yes [}' it tional~s~vy req'd: Yes [~ No ^ APPROVED BY THE COMMISSION DATE: ~~~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submi m Du licate / ~.~~r!lfQ( ~j Conoco~hillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com October 27, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • ~a~:~ ~~ ~ Zoo6 ~~S~ ~i. Re: Applications for Permit to Drill, West Sak Injector, iJ-136 and 1J-136 Ll Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a dual lateral horizontal well in the West Sak "B"and "D" sands. The main bore of the well will be designated 1J-136, and the lateral bore of the well will be designated 1J-136L1. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-136 is November 13, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, __ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ~ ~ C, ! ~ ~ ~~~~% ALASKA OIL AND GAS CONSERVATION COMMISSION / PERMIT TO DRILL ~~~~ ~ ~ ` i"` ~ ,>x~'~ ~~~`~~~ik~~~n 20 AAC 25.005 ~ ~ ~` ''w; 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methan ~^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single We Bond No. 59-52-180 11. Well Name and Number: 1J-136 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17408' ND: 3 6' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1565' FSL, 2282' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25662 & 0058 West Sak Oil Pool Top of Productive Horizon: 875' FNL, 412' FEL, Sec. 11, T10N, R10E, UM 8. Land Use Permit: ALK 2177 4604 13. Approximate Spud Date: 11/13/2006 Total Depth: 1772' FSL, 441' FEL, Sec. 14, T10N, R10E, UM 9. Acres in Prope 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558931 y- 5945378 Zone- 4 10. KB Elev tion (Heignt ove c~): 40' RKB feet 15. Distance to Nearest Well within Pool: 1J-102L1 , 12242' 16. Deviated wells: Kickoff depth: 400 ft. Maximum Hole Angle: 91 ° deg 17. M imum Anticipated Pressures in psig (see 20 AAC 25.035) ownhole: 1611 psig Surface: 1217 psig 18. Casing Program ecificati S Setting Depth Quantity of Cement Size ons p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 120' 120' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3549' 40' 40' 3589' 2197' 680 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 95 40' 40' 9546' 3573' 630 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTCM 7 62' 9546' 3573' 17408' 3436' slotted liner X19 ~ PRESENT WELL CONDITION SUM911ARY (To be completed for Redrill and Re-Entry Operations) Casing Length S' a Cement Volume MD ND Conductor/Structural Surface Intermediate Production IC/ Liner r Perforation Depth MD (ft): iJ( `,~ Perforation Depth ND (ft): V ~ \\ 20. Attachments: Filing Fee / BOP Sketch^ Drilling ProgramQ Time v. Depth Plot Shallow Hazard Analysis / Property Plat Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission presentative: Date: 22. 1 hereby certify that the foreg g is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ` - Phone Z.6~6$ 3 ~ Date `~ l2L /p~ P r n Al k Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 50- Date: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ^ Samples req'd: Yes ^ No ^ Mud log req'd: Yes ^ No ^ Other: H2S measures: Yes ^ No ^ Directional svy req'd: Yes ^ No ^ DATE: APPROVED BY THE COMMISSION Form 10-401 Revised 12/2005 ~ ~ \ t V /< i • • ` "'~ Submit in Duplicate Permit It -West Sak Well #1J-136 Application for Perjnit to Drill Document Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ ..............................................•--............,...................................-•--•-•-•-•- 2 2. Location Summary ..................................................................................................... 2 Requirements. of 20 AAC 25.OOS(c)(2) ......................................................................................................... 2 Re uirements o 20 AAC 25.050 ................................................... 3 q f ~) .......................................................... 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 2S.OOS(c)(3) ...................................•---.................................................................. 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 4 Requirements of 20 AAC 2S.OOS(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) ......................................................................................................... 4 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) ................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .................................................... 5 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ..............•--• •-•--................................................................_.............. 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 1J-136 PERMIT IT Page 1 of 7 Printed: 26-Oct-O6 ~~~~~ ~tion for Permit to Drill, Well 1J-136 Revision No.O Saved: 26-Oct-06 ,~~~~a r.~ ~~ r ~~~~~ MdxirttiixE 1Mell StQlue • ~tion for Permit to Drill, Well 1J-136 Revision No.0 Saved: 26-Oct-06 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ............................................................:......................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 7 15. Attachments ............................................................................................................... 7 Attachment 2 Directional Plan .......................................................•---...................-•-•---............................. 7 Attachment 3 Drilling Hazards Summary ........................................•---........._............................................. 7 Attachment 4 CemCADE Summary .........................................................................,........................---........ 7 Attachment 5 Well Schematic ........................................................................................................•-•-•------• ~ L Well Name Requirements of 20 AAC 25.005 (~ Each well mtest be 'ideratifred by a unique name designated by the operator and ca unique API nunahet• assigned lav the commission tender 20 AAC 25.040(Z?). For a well with multiple well branches, each branch rraaast similarly be identified by a tmigtae name and Al'I number by adding a sutfi_x to tlae ncante designated,fcrr the wellhy the operator ar2d to the number assigned to the well by the corrtartission. The well for which this Application is submitted will be designated as 1J-136. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Anrappliccztion for a Permit to 1?rill must he aceornpanied by each of the, following items, e~cept•for can item czlreadv on fzle with the corrantission and identfed in the application: (2) a plat iderttijying the propert)~ and the proper?y's owners and showing (AJthe Boor^dinates of the proposed location of the well cif the surface, at the top of each objective fcrrrnatiora,, and at total depth, referenced to governmental section lines. (6} the coordinate=s ref the proposed location of the well at the surface, referenced to the state plane coordinate systent•firr thzs state as maintar.'ned by the r~'cztional Geodetic Survev in fhe .National Oceanic and Atmospheric Administrations; (C) t12e proposed depth of the well at the top of each ofiiective formation and at total depth; Location at Surface 1,565' FSL, 2282' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,378 Eastings: 558,931 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 875' FNL, 412' FEL, Section 11, T10N, R10E Sak "B" Sand ASP z 4 NAD 27 Measured Depth, RKB: 9,495 one Coordinates Northin s: 5 937 674 Eastin s • 560 869 Total Vertical Depth, RKB: 3,568 g , , g . , Total Vertical De th, SS.• 3,447 Location at Total Depth 1,772' FSL, 441' FEL, Section 14, T10N, R10E " ASP Z 4 NAD 27 Measured Depth, RKB: 17,408 • one Coordinates Northin s: 5 929 910 763 Eastin s: 560 Total Vertical Depth,. RKB: 3,436 g , , g , Total Vertical Depth, SS: 3,315 and (D) other infcrrrnation required by 20 AAC 25.0~0(h); 1J-136 PERMIT IT Page 2 of 7 ®~ ~ ^ ~ ` ! A ! Punted: 26-Oct-06 • ~tion for Permit to Drill, Well 1J-136 Revision No.O Saved: 26-Oct-06 Requirements of 20 AAC 2S.OS0(b) If ~u well is to be iratentionully deviated: the application for a Permit to Drill (Farm 10-~01) rmzsi {1) include u plat, drawn to a szaftable scale, showing thel)ath of the proposed wellbnre, iraclzrdirag all adjacent wc;llbores within 200 feet of any portion of the proposed weal; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed 'tt~ellbore (A) list the names of the operators orthose wells, to the extent that those names are known or discoverable in public records, and show that each narraed operator- has been ftzrnished a copy of the application by certified rrtail; or (13) state that th<: applicant is the only affected owner. The Applicant is the only affected owner. 3. .Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application fin- a Permit to Drill must he accompanied by each of the following items, exc art f~)r an item already on file with rite commission and identified in the application: (3) a diagram artd description of the blowout prevention equipment (BOI'E) as required by 20 A.4C 2 5.035,, 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 drilTand complete well 1J-136. Please see. information on the. Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An tipplication for a Permit to Drill must be accompanied by each of the:following items, except,for an item already on file with the corttmission and ident~ed in the application: (4) infhrmatwn on drilling hazards, including (9) the maa."mare dowrahole pressure that mczv be ertcotmtered criteria used to determine it, and maximurra potentirrl.surfczce1)ressame based on a methane gradicni; The expected reservoir pressure in the West Sak sands in the 1J-136 area is 0.45 psi/ft, or 8.6 ppg EMW (equivalent ' mud weight). The maximum potential surface pressure (MPSP) is 1,217 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 3,581'. The MPSP is: MPSP = (3,581 ft)(0.45 - 0.11 psi/ft) =1,217 psi (B) data ran potential gas zones; The well bore is not expected to penetrate any gas zones. grad (C) data concerning potential causes of hole problems such as abnormzally geo-pressured strata, lost circulation zones, and zones that have a propensity, for differential sttckirtg; Please see Attachment 2: 1J-136 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Perrrait to Drill must be acconapanicd by each of the. following items, kept for art item ralreacfv on ftle with the t~ontmission and identfed in the application: {5) u description of tlae procedzrre fr)r conducting for-rraation integriiy tests, as required under 20 AAC 23.0300; 1J-136 will be completed with 9-5/8" casing landed at the top of the West Sak "B" 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 ConcocoPhillips Alaska placed on file with the Commission. 1J-136 PERMIT IT Page 3 of 7 Printed: 26-Oct-06 ORIGINAL • t~ation-for Permit to Drill, Well 1J-136 Revision No.0 Saved: 26-Oct-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) ~n 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: (a5) rt corrzplete proposed casing and cerraerating program as required by 20 AAC 2s.030, grad a description c~arty slotted liner, pre perforated liner, or screen to be installed; Casing and em -----•-•- See also Attachment 3: Cement Summar ~~~ Hole Top Btm Csg%I'bg Size Weight Length MD/TVD MD/TVD OD in in b/ t Grade Connection t t t 20" 40" 62.5 H-40 Welded 80 40' / 40' 120' / 120' ~' 13-3/8" 16" 68 L-80 BTC 3,549 40' / 40' 3,589' / 2,197' c 9-5/8" 12-1/4" 40 L-80 BTCM 9,506 40' / 40' 9,546' / 3,573' 4-1/2 6-3/4" B Sand Lateral 11.6 L-80 BTCM 862 7 546' / 3 573' 9 408' / 3 436' 17 slotted (1J-136). , , , , , slotted 6-3/4" D Sand Lateral (1J-136 Ll) 11.6 L-80 BTCM 8,001 9,100' / 3,505' 17;101' / 3,373' Slotted-no cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application firr a Permit to Drill must be accompartic;d by each °f ihe,fcrllowing items, except for an item already on,file with flze commission and identified in the application: (?) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the cwnrnission under A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1J- 136. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) Ara application, for a Permit to Drill must be accompanied 1}y each of the fotlowirag items, ea-cept for an item already on fie with the commzssion and identified in the application: (8) a drilling, fluid program, including a cliagrcam and description of the drilling fluid system, as required by 20 AAC 25.O33; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Initial Value Final Value Density (pp~ 8.5 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50-70 50-70 30-50 30-50 cP Plastic Viscostty 20-45 20-45 15-20 15-20 b/100 s pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate (cc / 30 min)) NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 *9.6 ppg if hydrates are encountered ORIGINAL 1J-136 PERMIT IT Page 4 of 7 Printed: 26-Oct-O6 • ~tion for Permit to Drill, Well 1J-136 Revision No.O Saved: 26-Oct-06 Intermediate Hole Mud Program (LSND) 13-3/8"Casing Shoe to Intermediate Casio Point Initial Value Density (pg) 9.0-9.1 Funnel Viscosity 45-60 (seconds) Plastic Viscostiy 12-18 (lb/100 s Yield Point 26-35 (~P) API Filtrate 4-6 (cc / 30 min)) Chlorides (mg/Z) <500 H 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value . Density (ppg) - 9.0 Plastic Viscostiy 15-25 (lb/100 s Yield Point (cI') 18 28 HTHP Fluid loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical Stabili >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application frlr a Permit to Drill mtast he accompartied l?v each of the,following iterris, except frr an Item already ort_~le with the commission farad identifted in floe application: (9) for an exploratory or straiigraphic test well, a tabztlation setting out the depths of predicted alrnornuzlly gees Frressaared strata as required by 2D fL4C 25.(133(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 ca Permit to Drill must be accorttpanied by each of the.following items, kept for fart item already on file with the cornntission and identified in the application: {70J for an exploratory or stratigr^aphic test weld, a seismic rrfraction or reflection analysis as required by 20,ifiC 25.(lhf (ca); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) r1n application fin a Permit to Drill roust be accompartied by each of t'he,following items, e<ecaF~t for an item ah-ecatly ora 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, arz analysis of seabed conditions cis required by 20 _A.4C 25. (I61(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) _An applicaiion for a Permit to Drill must he accompanied by each of the. following items, except for an item already on file ~+ith the commission and ident~ed in the capplicalion: (72) evidence showing chat the requirements ~ f 2U rIAC 2S. 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 mtast be accompartied by each c f the f rllowing items, except for an item ah~eady on.rle a=ith the eommissior2 artd identified in the eapplieation: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1J-136 PERMIT IT Page 5 of 7 Printed: 26-Oct-O6 ~~IGII~aL A~tion for Permit to Drill, Well 1J-136 Revision No.1 Saved: 6-Nov-06 ."" 1. Proposed Drilling Program ~- Revised -From Hybrid [13 3/8" x 9 5/8" x 4.5"] (] '~~ '?~C16 «~ to Big Bore [13 3/8" x 9 5/8" x 5.5"] Casing Design Requirements of 20 AAC 25.005 (c)(13) A,las~a fl~~ 1?~ ~~~ C9cts. Commission ~1r2 appldcatio~s, for it YermU Iv Drill rrusst he cu•companzed fw each of the fbllowirag itelru, ea-ceptfiir an item alrect~~p an, file a~~~~8zisstors and iclenii/led iiz the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 121' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,589' MD / 2,197' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-Si8" 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 12-1/4" 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. 8. Directionally drill to 9-5/8" casing point at 9,546' MD / 3,573' TVD, the prognosed top of the B sand. 9. Run 9-Si8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 6,045' MD, 500' above the Ugnu C). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 1 L Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 12. PU 8-1/2" 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. 14. Directionally dri118-1/2" hole to TD at +/- 17,408' MD / 3,436' TVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. 16. Run USIT log for cement bond. 17. PU and run 5-1/2" slotted liner. 18. Land liner, set liner hanger @ +/- 9,200' MD. (100' below D window) POOH. Note: Remaining operations are covered under the 1J--136 LI Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 9,100' MD / 3,505' TVD, near the top of the "D" sand. 20. Mi118-1/2" window. POOH. Z L Pickup 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of "D" sand lateral at 17,101' MD ! 3,373' TVD, as per directional plan. 7J-136 PERMIT IT F1NAL BIG BORE Page 1 of 2 Printed: 6-Nov-O6 . ~ f~ation for Permit to Drill, Well 1J-136 Revision No.1 Saved: 6-Nov-06 23. POOH, back reaming out of lateral. POOH. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 5-1/2" 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. 29. POOH, laying down drill pipe as required. 30. PU completion as required and RIH to depth. Land tubing. Set BPV. 31. Nipple down BOPE, nipple up tree and test. Pull BPV. 32. Freeze protect well with diesel by pumping into ~-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 33. Set BPV and move rig off. 34. Rig up wire line unit. Pull BPV. 35. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 36. Rig up wireline. Replace gas lift valves with blank dummy valves. 3 7. Turn well over to operations. .~~a~9ca ~~ G~t~ ~:t~t~s. ~~~~r~i~s;r~ ~rlchora 1J-136 PERMIT IT FINAL BIG BORE Page 2 of 2 Printed.' 6-Nov-06 ~ation for Permit to Drill, Well 1 J-136 Revision No.O Saved: 26-Oct-06 1. Excavate cellar, install cellar box., set and cement 20" x 34" insulated conductor to +/- 121' RKB. Insta landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Instal121-1/4" Annular with 16" diverter line and function test. 3, Spud and directionally drill 16" hole to casing point at+/- 3,589' MD / 2,197' TVD as per di ctional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud nd, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described a ove in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD &PWD. RIH, clean out ce ent 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 formati integrity test to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 9,546' MD / 3,573' TVD the prognosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement nd displace with mud (top of cement to be 6,045' MD, 500' above the Ugnu C). Pressure test casing to 3,000 psi r 30 minutes and record results. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. SvQ~~~ c~ it ~~ .-~ ~ 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by di el. ~~ 12. PU 6-3/4" drilling assembly, with MWD, and LWD log ng tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet ove the float collar 13. Drill out.cement and between 20' and 50' of new ho Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. 14. Directionally dri116-3/4" hole to TD at +/- 17,4 ' MD / 3,436' TVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. 16. Run USIT log for cement bond. 17. PU and run 4-1/2" slotted liner. 18. Land liner, set liner hanger @ +/- 9,2 ' MD. (100' below D window) POOH. Note: Remaining operations are cov red under the IJ--136 LI Application for Permit to Drill, and areprovided here for information only. 19. Run and set Baker WindowM ter whipstock system, at window point of 9,100' MD / 3,505' TVD, near the top of the "D" sand. 20. Mi116-3/4" window. POO 21. Pick up 6-3/4" drilling as embly with LWD and MWD and PWD. RIH. 22. Drill to TD of "D" san ateral at 17,101' MD / 3,373' TVD, as per directional plan. 23. POOH, back reaming ut of lateral. POOH. 24. RIH with whipstoc retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2' slotted liner. 26. RIH, until liner anger is just above window. Orient hanger to window and land hanger. 27. Release hang ~ running tool. POOH. 28. Make up ju ction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH. to depth. Orient and set packer ato,~ assembly and release from assembly. 1J-136 PERMIT IT Page 6 of 7 Printed: 26-Oct-06 G~IGIN~L • 29. POOH, laying down drill pipe as required. 30. PU completion as required and RIH to depth.. Land tubing. Set a~ation for Permit to Drill, Well 1J-136 Revision No.O Saved: 27-Oct-06 31 ~ Nipple down BOPE, nipple up tree and test. Pull BPV 32. Freeze protect well with diesel by pumpin 0 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 33. Set BPV and move rig off. S ~ ~CC~CJ C~ ~ `I~o ~ 34. Rig up wire line unit ull BPV. d~~~~ 35. Set gas lift val~s in mandrels. Operate well on gas lift until ESP facilities are ready. 36. Rig up ' eline. Replace gas lift valves with blank dummy valves. 37. T well over to operations. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) Art application fa• a Permit to Drill ntustc be accompanied by each of the fulloxvirag items, except for an item alreadv ort file with the cornrnission and identified ira the application: (14) a general description of hnw the operator plans to dispose of drilling mud and cuttings arzd a staternerat of whelhgr thr: olerator intends to request authorizrttior2 ztnder 20 AAC 2J.080 for an anmtlar disposal operation in the ii~ell.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, ox by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and InjectFacility 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 CemCADE Summary Attachment 4 Well Schematic 1J-136 PERMIT IT Page 7 of 7 Printed: 27-Oct-06 OR161NAL • ,.. / ConocoPhillips Alaska Plan: 1J-136 (wp08) Sperry Drilling Services Proposal Report -Geographic 24 October, 2006 Local Coordinate Qrigin: Viewing Datum: TVDs to System: North Reference: Unit System: ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-136 1 J-136 Centered on Well Plan 1J-136 Doyon 15 (40+81) C~ 121.OOft (Doyon 15 (40+g1)) N ,t _.. .._. " _ .. .... __ _z.._ ._. .. _ ~. _~,. ~ _...~. ~'3 . _ .. ._ _ . ..1. ~ _ W __ ~_ "} E ... _ _ - - True API - US Survey Feet Sperry Drilling Services ORIGINAL Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-136 Wellbore: 1 J-136 Plan: 1J-136 (wp08) -3000 WELL DETAILS: Plan 1J-136 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 5945377.60 558931.10 70°15'40.916N 149°31'25.022W FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1514.00 1393 1619.97 Permafrost 2 1662.00 1541 1831.37 K15 3 1985.62 1864.62 2711.68 T3 4 2197.17 2076.17 3588.54 T3+550 5 2910.40 2789.4 6544.80 Ugnu C 6 3117.92 2996.92 7404.95 Ugnu B 7 3183.40 3062.4 7676.36 Ugnu A 8 3365.74 3244.74 8432.13 K13 9 3504.50 3383.5 9097.43 West Sak D 10 3548.52 3427.52 9350.92 West Sak C 11 3568.11 3447.11 9494.88 West Sak B Slot CASING DETAILS No TVD MD Name Size 1 3572.72 9546.32 9 518" 9-518 2 3436.01 17408.00 4112" 4-112 3 2197.17 3588.53 13 318" 13-318 SHL: 1564' FSL, 2282' FEL -Sec 35-T11N-R10E -1000 KOP -Begin Dir 2.5°/100' ~ 400' MD, 400' ND ' Continue Dir 4°I700' ~ 714' MD, 713' ND 0 _- ~ - ---_ - - ~ - 20° 0 End Dir ~ 1619' MD, 1513' ND BHL 17408' MD, 3436' ND: 1773' FSL, 441' FEL - Sec14-T10N-R10E - 1000 100 , ~ ' Begin DIR 5°I100' LID 1719' MD, 1585' ND Begin DIR 3 °/100' ~ 9350' MD, 3548' ND - ~ ~ ~ Perrtiariosr ° ~ t+~ - ~ "~ ~~ ; , - , -- -'190 ,~' ___-- _ - - - - End DIR ~ 2359' MD, 1900' ND ~ End DIR ~ 9020' MD, 3491' TVD,' End DIR ~ 951T MD, 3570' ND - ° ~ ~ ~ o o w t 000 ._ - T3 ~ _ _ _ _ 0 °- - o - - - "~ o Begin DIR 3°/100' ~ 8513' MD, 3385' Nd ~ ~ , ~ ~ End DIR ~ 9778' MD, 3581' ND -a a° _ o , - , _ ~ -- _ ~' ~ + _ --- n ~ ~ L cnu C~ Ugnu 8 ° ° ~ ` ~ t°o o '~ ~ , - Geosteer in the B-Sand ~ 10298' MD, 3574' TVD 0 ~ ' - g '/ X3000 > -;_--- _. _ _~ -K13- _-- i ` _ ~ 4 , - ~ ~ _.. ~ $~ c ~ ~ _.- _ c.~ ; ,:. - - _. -_: 1J-136 l1 (wpGBj - i -..: _.. _ - ~ West Sak D ' ` , ~ ~ ~\ o '~ ~ o ~i o e $ ° o i o o ° ° ° ° ~ ° p ~ ° 4000 FL'esfSakC o A o ~ ° o i ` , ~ ° ° ~ ' i ` i i ~ i ~ 41/2", Nest ~ai~. 5 13 3/8" Csg - 3589' MD, 2197 ND: 581' FNL, 1709' FEL -Sect-T10N-R10E ~ ~ ~ i ~ ~ i ~ ~ ~ 08 T 8 1 13 ~ 6 wp T i J- 1J-136 wp08 U To i ~ 1J-136 wp0 r ` ' ~ 5000 1J-136 wp08 T ~ 1J-136 wp08 B To 1J-136 wp08 8 To 95/8" Csg -Begin DIR 2.5°/100' ~ 9546' MD, 3573' TVD: 927' FNL, 412' FEL - Sec11-T10N-R10E 6000 ~" ~ ConocoPhillips ~ , _.. , ._, - --- - ~rillin and FormaClon Alaska g Evaluation -2000 -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 Vertical Section al 180-00` (2000 (t/in) 1 SHL: 1564' FSL, 2282' FEL ~ 35-T11 N-R10E KOP Begin Dir 2.5°/100' @ 400' MD, 400' TVD ~- - - - - - - - - Continue Dir 4°/100' @ 714' MD, 713' TVD 10p0 ------- ----____----EndDir@1619'MD, 1513'TVD Begin DIR 5°/100' @ 1719' MD, 1585' TVD 20p0 End DIR @ 2359' MD, 1900' TVD ---13 3/8" Csg - 3589' MD, 2197' TVD: 581' FNL, 1709' FEL -Sect-T10N-R10E 165° L 0 N Begin DIR 3°/100' @ 8513' MD, 3385' TVD End DIR @ 9020' MD, 3491' TVD 3p00 Begin DIR 3 °/100' @ 9350' MD, 3548' TVD . - ~ End DIR @ 9517' MD, 3570' TVD ' 170, - 1J-136wp08DTop - -188°__ ________________ 1J-136 wp08 B Top - _ - 9 5/8" Csg -Build 2.5°/100' @ 9546' MD, 3573' TVD: 927' FNL, 412' FEL - Sec11-T10N-R10E 180° End DIR @ 9778' MD, 3581' TVD 180° Geosteer in the B-Sand @ 10298' MD, 3574' TVD 1J-136 wp08 T2 - - 180° {-1 1J-136 wp08 T3 1J-136 wp08 T4 180° r M Magnetic North: 24.65° Magnetic Field Strength: 57552.4nT Dip Angle: 80.75° Date: 11 /18/2004 Model: BGGM2005 180° ConocoPhillips Alaska _. _ _ BHL 17408' MD, 3436' TVD: 1773' FSL, 441' FEL - Sec14-T10N-R10E Ewa;;,"a io,~~ Formotion 4 1 /2" 1J-136 wp08 B Toe - looo 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 West(-)/East(+) (1750 ft/in) ORIGINAL ,, ConocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic ~,~~z Driinng and Formation Evaluation Database: _EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TUD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 1 S (40+81)) Site: Kuparuk 1J Pad North Reference: True ~ Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature W e l l bore: 1 J-136 ~ Design: 1J-136 (wp08) 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-136 Well Position +N/-S 0.00 ft Northing: 5,945,377.60 R Latitude: 70° 15' 40.916" N +E/-W 0.00 ft Easting: 558,931.10 ft Longitude: 149° 31' 25.022" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft Wetibore 1J-136 Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2005 11/18/2004 24.65 80.75 57,552 Design 1J-136 i:vp031 Audit Notes: Version: 26 Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth Fram {TVD) +N/-S +EI-W Direction {ft) {ft) (ftl (°) 40.00 0.00 0.00 180.00 10/24/2006 4:11:28PM Page 2 of 10 COMPASS 2003.11 Build 50 '~~?I~~x • Car~t~+~oPhillps Halliburton Energy Services Planning Report -Geographic Grilling end Formation Evaluation .............. Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: ?Ian 1J-136 Survey Galcutation Method: Minimum Curvature Wellbore: 1 J-136 I Design: 1J-136 (wp08) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/_S +E/-W Rate Rate Rate TFO (ffl (°} (°) {ft) eft) (ftl (°/100ft) (°1100ft) (°/100ft) ~~~ 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 0.00 0.00 O.DO 0.00 0.00 713.98 7.85 164.98 713.00 -20.74 5.57 2.50 2.50 0.00 164.98 1,618.58 44.03 164.98 1,513.00 -396.62 106.42 4.00 4.00 0.00 0.00 1,718.58 44.03 164.98 1,584.89 -463.75 124.44 0.00 0.00 0.00 0.00 2,358.69 76.04 164.98 1,900.46 -992.43 266.27 5.00 5.00 0.00 0.01 8,512.70 76.04 164.98 3,385.18 -6,760.70 1,813.69 0.00 0.00 0.00 0.00 9,020.31 80.00 180.02 3,491.11 -7,251.44 1,877.80 3.00 0.78 2.96 76.58 9,100.31 80.00 180.02 3,505.00 -7,330.22 1,877.78 0.00 0,00 0.00 0.00 9,350.31 80.00 180.02 3,548.41 -7,576.42 1,877.69 0.00 0,00 0.00 0.00 9,516.85 85.00 179.95 3,570.15 -7,741.48 1,877.74 3.00 3.00 -0.04 -0.81 9,546.32 85.00 179.95 3,572.72 -7,770.85 1,877.76 0.00 0.00 0.00 0.00 9,778.14 90:79 180.05 3,581.24 -8,002.41 1,877.77 2.50 2.50 0.04 0.95 10,297.66 90.79 180.05 3,574.07 -8,521.88 1,877.37 0.00 0.00 0.00 0.00 10,306.15 90.86 179.80 3,573.95 -8,530.37 1,877.38 3.00 0.82 -2.89 -74.14 11,102.37 90.86 179.80 3,562.00 -9,326.49 1,880.16 0.00 0.00 0.00 0.00 11,121.98 91.29 180.20 3,561.63 -9,346.10 1,880.16 3.00 2.21 2.03 42.65 12,923.03 91.29 180.20 3,521.00 -11,146.68 1,873.91 0.00 0.00 0.00 0.00 12,926.72 91.31 180.09 3,520.92 -11,150.37 1,873.90 3.00 0.57 -2.95 -79.13 14,362.57 91.31 180.09 3,488.00 -12,585.84 1,871.65 0.00 0.00 0.00 0.00 14,375.43 90.98 180.28 3,487.74 -12,598.70 1,871.61 3.00 -2.61 1.47 150.58 17,408.32 90.98 180.28 3,436.00 -15,631.11 1,856.82 0.00 0.00 0.00 0.00 10/24/2006 4:11:28PM Page 3 of 10 COMPASS 2003.11 Build 50 ~~~lNAL ConocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic Grilling and Formation Eveluatlon Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Site: Kuparuk 1J Pad North Reference: True WeII: Plea 1 J-136 Survey Calculation Method: Minimum Curvature' Wellbore: 1J-1'_~~i Design: 1J-133 (wp08) Planned Survey 1J-136 ic~~pOBi Map Map MD Inclination Azimuth TW SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ff1 fff1 (f~) (ft) Iftl (ft) t°1loonl ('ft) 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,377.60 558,931.10 0.00 0.00 SHL: 1564' FSL, 2282' FEL -Sec 35-T1 1N-R10E 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,377.60 558,931.10 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,377.60 558,931.10 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 5,945,377.60 558,931.10 0.00 0.00 400.00 0.00 0.00 400.00 279.00 0.00 0.00 5,945,377.60 558,931.10 0.00 0.00 ' KOP -Begin Dir 2.5°/100' @ 400' MD, 400' TVD 500.00 2.50 164.98 499.97 378.97 -2.11 0.57 5,945,375.50 558,931.68 2.50 2.11 600.00 5.00 164.98 599.75 478.75 -8.42 2.26 5,945,369.20 558,933.43 2.50 8.42 700.00 7.50 164.98 699.14 578.14 -18.94 5.08 5,945,358.71 558,936.33 2.50 18.94 713.98 7.85 164.98 713.00 592.00 -20.74 5.57 5,945,356.91 558,936.83 2.50 20.74 Continue Dir 4°/100' @ 714' MD, 713' TVD 800.00 11.29 164.98 797.81 676.81 -34.55 9.27 5,945,343.13 558,940.64 4.00 34.55 900.00 15.29 164.98 895.11 774.11 -56.75 15.23 5,945,320.98 558,946.77 4.00 56.75 1,000.00 19.29 164.98 990.57 869.57 -85.45 22.93 5,945,292.34 558,954.69 4.00 85.45 1,100.00 23.29 164.98 1,083.73 962.73 -120.51 32.34 5,945,257.36 558,964.37 4.00 120.51 1,200.00 27.29 164.98 1,174.13 1,053.13 -161.76 43.40 5,945,216.20 558,975.77 4.00 161.76 1,300.00 31.29 164.98 1,261.32 1,140.32 -209.01 56.08 5,945,169.06 558,988.81 4.00 209.01 1,400.00 35.29 164.98 1,344.90 1,223.90 -262.01 70.30 5,945,116.18 559,003.44 4.00 262.01 1,500.00 39.29 164.98 1,424.44 1,303.44 -320.51 86.00 5,945,057.80 559,019.60 4.00 320.51 1,600.00 43.29 164.98 1,499.56 1,378.56 -384.23 103.10 5,944,994.22 559,037.19 4.00 384.23 1,618.58 44.03 164.98 1,513.00 1,392.00 -396.62 106.42 5,944,981.86 559,040.61 4.00 396.62 End Dir ~ 16 19' MD, 1513' TVD 1,619.97 44.03 164.98 1,514.00 1,393.00 -397.55 106.67 5,944,980.93 559,040.87 0.00 397.55 Pemtafrost 1,700.00 44.03 164.98 1,571.54 1,450.54 -451.28 121.09 5,944,927.32 559,055.71 0.00 451.28 1,718.58 44.03 184.98 1,584.89 1,463.89 -463.75 124.44 5,944,914.88 559,059.15 0.00 463.75 Begin DIR 5°/100' @ 1719 ' MD, 1585' ND 1,800.00 48.10 164.98 1,641.37 1,520.37 -520.38 139.63 5,944,858.38 559,074.78 5.00 520.38 1,831.37 49.67 164.98 1,662.00 1,541.00 -543.20 145.75 5,944,835.61 559,081.09 5.00 543.20 K15 1,900.00 53.10 164.98 1,704.82 1,583.82 -594.99 159.65 5,944,783.93 559,095.38 5.00 594.99 2,000.00 58.10 164.98 1,761.29 1,640.29 -674.66 181.02 5,944,704.44 559,117.38 5.00 674.66 2,100.00 63.10 164.98 1,810.36 1,689.36 -758.78 203.59 5,944,620.50 559,140.61 5.00 758.78 2,200.00 68.10 164.98 1,851.65 1,730.65 -846.72 227.18 5,944,532.77 559,164.88 5.00 846.72 2,300.00 73.10 164.98 1,884.85 1,763.85 -937.79 251.62 5,944,441.90 559,190.02 5.00 937.79 2,358.69 76.04 164.98 1,900.46 1,779.46 -992.43 266.27 5,944,387.38 559,205.11 5.00 992.43 End DIR ~ 2359' MD, 190 0' TVD 2,400.00 76.04 164.98 1,910.43 1,789.43 -1,031.15 276.66 5,944,348.75 559,215.80 0.00 1,031.15 2,500.00 76.04 164.98 1,934.55 1,813.55 -1,124.88 301.81 5,944,255.22 559,241.67 0.00 1,124.88 2,600.00 76.04 164.98 1,958.68 1,837.68 -1,218.61 326.95 5,944,161.70 559,267.55 0.00 1,218.61 2,700.00 76.04 164.98 1,982.80 1,861.80 -1,312.35 352.10 5,944,068.18 559,293.42 0.00 1,312.35 2,711.68 76.04 164.98 1,985.62 1,864.62 -1,323.29 355.03 5,944,057.25 559,296.44 0.00 1,323.29 T3 10/24/2006 4:11:28PM Page 4 of 10 COMPASS 2003.11 Build 50 ;?R!GINAL C©i"tOCf?P~'11~{f~35 Halliburton Energy Services ~ ~- Planning Report -Geographic Grilling and Formation AlaskH Evaluation s Database: _EDM_2003.11_b48 Local Co-oMinate Reference: Well Plan 1J-136 Company: l ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) i Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wel Ibore: 1 J-136 Design: 1J-136 (wp08) Planned Survey 1J-136 (wp08) Map Map MD I nclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft1 (°) (~) (ft) (ft) lft) (ft) (ft) lft) (°/100ft) Iftl 2,800.00 76.04 164.98 2,006.93 1,885.93 -1,406.08 377.24 5,943,974.65 559,319.30 0.00 1,406.08 2,900.00 76.04 164.98 2,031.06 1,910.06 -1,499.81 402.39 5,943,881.13 559,345.17 0.00 1,499.81 3,000.00 76.04 164.98 2,055.18 1,934.18 -1,593.54 427.53 5,943,787.61 559,371.05 0.00 1,593.54 3,100.00 76.04 164.98 2,079.31 1,958.31 -1,687.27 452.68 5,943,694.08 559,396.92 0.00 1,687.27 3,200.00 76.04 164.98 2,103.43 1,982.43 -1,781.01 477.82 5,943,600.56 559,422.80 0.00 1,781.01 3,300.00 76.04 164.98 2,127.56 2,006.56 -1,874.74 502.97 5,943,507.04 559,448.67 0.00 1,874.74 3,400.00 76.04 164.98 2,151.69 2,030.69 -1,968.47 528.11 5,943,413.51 559,474.55 0.00 1,968.47 3,500.00 76.04 164.98 2,175.81 2,054.81 -2,062.20 553.26 5,943,319.99 559,500.42 0.00 2,062.20 3,588.53 76.04 164.98 2,197.17 2,076.17 -2,145.18 575.52 5,943,237.20 559,523.33 0.00 2,145.18 13 318" Csg - 3589` MD, 219T TW: 581' FNL,1709' FEL -Sect-T1 ON-R10E - T3+550 - 13 3/8" 3,600.00 76.04 164.98 2,199.94 2,078.94 -2,155.93 578.40 5,943,226.47 559,526.30 0.00 2,155.93 3,700.00 76.04 164.98 2,224.06 2,103.06 -2,249.66 603.55 5,943,132.94 559,552.17 0.00 2,249.66 3,800.00 76.04 164.98 2,248.19 2,127.19 -2,343.40 628.69 5,943,039.42 559,578.05 0.00 2,343.40 3,900.00 76.04 164.98 2,272.32 2,151.32 -2,437.13 653.84 5,942,945.90 559,603.92 0.00 2,437.13 4,000.00 76.04 164.98 2,296.44 2,175.44 -2,530.86 678.98 5,942,852.37 559,629.80 0.00 2,530.86 4,100.00 76.04 164.98 2,320.57 2,199.57 -2,624.59 704.12 5,942,758.85 559,655.67 0.00 2,624.59 4,200.00 76.04 164.98 2,344.69 2,223.69 -2,718.32 729.27 5,942,665.33 559,681.55 0.00 2,718.32 4,300.00 76.04 164.98 2,368.82 2,247.82 -2,812.06 754.41 5,942,571.80 559,707.42 0.00 2,812.06 4,400.00 76.04 164.98 2,392.95 2,271.95 -2,905.79 779.56 5,942,478.28 559,733.30 .0.00 2,905.79 4,500.00 76.04 164.98 2,417.07 2,296.07 -2,999.52 804.70 5,942,384.76 559,759.17 0.00 2,999.52 4,600.00 76.04 164.98 2,441.20 2,320.20 -3,093.25 829.85 5,942,291.23 559,785.05 0.00 3,093.25 4,700.00 76.04 164.98 2,465.32 2,344.32 -3,186.98 854.99 5,942,197.71 559,810.93 0.00 3,186.98 4,800.00 76.04 164.98 2,489.45 2,368.45 -3,280.72 880.14 5,942,104.19 559,836.80 0.00 3,280.72 4,900.00 76.04 164.98 2,513.58 2,392.58 -3,374.45 905.28 5,942,010.66 559,862.68 0.00 3,374.45 5,000.00 76.04 164.98 2,537.70 2,416.70 -3,468.18 930.43 5,941,917.14 559,888.55 0.00 3,468.18 5,100.00 76.04 164.98 2,561.83 2,440.83 -3,561.91 955.57 5,941,823.62 559,914.43 0.00 3,561.91 5,200.00 76.04 164.98 2,585.95 2,464.95 -3,655.64 980.72 5,941,730.09 559,940.30 0.00 3,655.64 5,300.00 76.04 164.98 2,610.08 2,489.08 -3,749.38 1,005.86 5,941,636.57 559,966.18 0.00 3,749.38 5,400.00 76.04 164.98 2,634.21 2,513.21 -3,843.11 1,031.01 5,941,543.05 559,992.05 0.00 3,843.11 5,500.00 76.04 164.98 2,658.33 2,537.33 -3,936.84 1,056.15 5,941,449.52 560,017.93 0.00 3,936.84 5,600.00 76.04 164.98 2,682.46 2,561.46 -4,030.57 1,081.30 5,941,356.00 560,043.80 0.00 4,030.57 5,700.00 76.04 164.98 2,706.58 2,585.58 -4,124.30 1,106.44 5,941,262.48 560,069.68 0.00 4,124.30 5,800.00 76.04 164.98 2,730.71 2,609.71 -4,218.03 1,131.59 5,941,168.95 560,095.55 0.00 4,218.03 5,900.00 76.04 164.98 2,754.84 2,633.84 -4,311.77 1,156.73 5,941,075.43 560,121.43 0.00 4,311.77 6,000.00 76.04 164.98 2,778.96 2,657.96 -4,405.50 1,181.88 5,940,981.91 560,147.30 0.00 4,405.50 6,100.00 76.04 164.98 2,803.09 2,682.09 -4,499.23 1,207.02 5,940,888.38 560,173.18 0.00 4,499.23 6,200.00 76.04 164.98 2,827.21 2,706.21 -4,592.96 1,232.17 5,940,794.86 560,199.05 0.00 4,592.96 6,300.00 76.04 164.98 2,851.34 2,730.34 -4,686.69 1,257.31 5,940,701.34 560,224.93 0.00 4,686.69 6,400.00 76.04 164.98 2,875.47 2,754.47 -4,780.43 1,282.46 5,940,607.82 560,250.80 0.00 4,780.43 6,500.00 76.04 164.98 2,899.59 2,778.59 -4,874.16 1,307.60 5,940,514.29 560,276.68 0.00 4,874.16 6,544.80 76.04 164.98 2,910.40 2,789.40 -4,916.15 1,318.87 5,940,472.39 560,288.27 0.00 4,916.15 Ugnu C 6,600.00 76.04 164.98 2,923.72 2,802.72 -4,967.89 1,332.75 5,940,420.77 560,302.55 0.00 4,967.89 6,700.00 76.04 164.98 2,947.85 2,826.85 -5,061.62 1,357.89 5,940,327.25 560,328.43 0.00 5,061.62 6,800.00 76.04 164.98 2,971.97 2,850.97 -5,155.35 1,383.04 5,940,233.72 560,354.30 0.00 5,155.35 6,900.00 76.04 164.98 2,996.10 2,875.10 -5,249.09 1,408.18 5,940,140.20 560,380.18 0.00 5,249.09 7,000.00 76.04 164.98 3,020.22 2,899.22 -5,342.82 1,433.33 5,940,046.68 560,406.05 0.00 5,342.82 7,100.00 76.04 164.98 3,044.35 2,923.35 -5,436.55 1,458.47 5,939,953.15 560,431.93 0.00 5,436.55 10/24/2006 4:11:28PM Page 5 of 10 COMPASS 2003.11 Build 50 ~ , 3 a ConocoPhiNips Alaska Halliburton Energy Services Planning Report -Geographic ~- € Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81 )) Site: KuparuklJ Pad North Referent®: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-136 Design: 1J-136 (wp08) Planned Survey 1J--136 ~wp08) Map MD Inclination Azimuth TVD SSND +N/-S +E/-W Northing Ift} (°) 1°) (ft} (ft} (ft) (ft) Ift) 7,200.00 76.04 164.98 3,068.48 2,947.48 -5,530.28 1,483.62 5,939,859.63 7,300.00 76.04 164.98 3,092.60 2,971.60 -5,624.01 1,508.76 5,939,766.11 7,400.00 76.04 164.98 3,116:73 2,995.73 -5,717.74 1,533.91 5,939,672.58 7,404.95 76.04 164.98 3,117.92 2,996.92 -5,722.38 1,535.15 5,939,667.95 Ugnu B 7,500.00 76.04 164.98 3,140.85 3,019.85 -5,811.48 1,559.05 5,939,579.06 7,600.00 76.04 164.98 3,164.98 3,043.98 -5,905.21 1,584.20 5,939,485.54 7,676.36 76.04 164.98 3,183.40 3,062.40 -5,976.78 1,603.40 5,939,414.12 Ugnu A 7,700.00 76.04 164.98 3,189.11 3,068.11 -5,998.94 1,609.34 5,939,392.01 7,800.00 76.04 164.98 3,213.23 3,092.23 -6,092.67 1,634.49 5,939,298.49 7,900.00 76.04 164.98 3,237.36 3,116.36 -6,186.40 1,659.63 5,939,204.97 8,000.00 76.04 164.98 3,261.48 3,140.48 -6,280.14 1,684.78 5,939,111.44 8,100.00 76.04 164.98 3,285.61 3,164.61 -6,373.87 1,709.92 5,939,017.92 8,200.00 76.04 164.98 3,309.74 3,188.74 -6,467.60 1,735.07 5,938,924.40 8,300.00 76.04 164.98 3,333.86 3,212.86 -6,561.33 1,760.21 5,938,830.87 8,400.00 76.04 164.98 3,357.99 3,236.99 -6,655.06 1,785.36 5,938,737.35 8,432.13 76.04 164.98 3,365.74 3,244.74 -6,685.18 1,793.44 5,938,707.30 K13 8,500.00 76.04 164.98 3,382.11 3,261.11 -6,748.80 1,810.50 5,938,643.83 8,512.70 76.04 164.98 3,385.18 3,264.18 -6,760.70 1,813.69 5,938,631.95 Begin DIR 3°/100' ~ 8513` MD, 3385' ND 8,600.00 76.66 167.60 3,405.78 3,284.78 -6,843.11 1,833.79 5,938,549.71 8,700.00 77.40 170.58 3,428.23 3,307.23 -6,938.79 1,852.23 5,938,454.19 8,800.00 78.18 173.55 3,449.37 3,328.37 -7,035.58 1,865.71 5,938,357.51 8,900.00 78.99 176.49 3,469.17 3,348.17 -7,133.22 1,874.21 5,938,259.95 9,000.00 79.83 179.43 3,487.55 3,366.55 -7,231.44 1,877.71 5,938,161.77 9,020.31 80.00 180.02 3,491.11 3,370.11 -7,251.44 1,877.80 5,938,141.77 End DIR @ 9020' MD, 3491' ND 9,097.43 80.00 180.02 3,504.50 3,383.50 -7,327.39 1,877.78 5,938,065.84 West Sak D 9,100.00 80.00 180.02 3,504.95 3,383.95 -7,329.92 1,877.78 5,938,063.31 9,100.31 80.00 180.02 3,505.00 3,384.00 -7,330.22 1,877.78 5,938,063.00 iJ-136 wp08 D Top 9,200.00 80.00 180.02 3,522.31 3,401.31 -7,428.40 1,877.74 5,937,964.84 9,300.00 80.00 180.02 3,539.68 3,418.68 -7,526.88 1,877.71 5,937,866.37 9,350.31 80.00 180.02 3,548.41 3,427.41 -7,576.42 1,877.69 5,937,816.83 Begin DIR 3 °/100' ~ 9350' MD, 3548' ND 9,350.92 80.02 180.02 3,548.52 3,427.52 -7,577.02 1,877.69 5,937,816.23 West Sak C 9,400.00 81.49 180.00 3,556.40 3,435.40 -7,625.47 1,877.68 5,937,767.79 9,494.88 84.34 179.96 3,568.11 3,447.11 -7,719.61 1,877.72 5,937,673.66 West Sak B Map Fasting (ft) 560,457.81 560,483.68 560,509.56 560, 510.84 560,535.43 560,561.31 560,581.06 560,587.18 560,613.06 560,638.93 560,664.81 560,690.68 560,716.56 560,742.43 560,768.31 560,776.62 560, 794.18 560, 797.47 560,818.21 560,837.39 560,851.63 560,860.90 560,865.16 560,865.41 560,865.98 Grilling and Formation Evaluation DLSEV Vert Section (°I100ft) {ft) 0.00 5,530.28 0.00 5,624.01 0.00 5,717.74 0.00 5,722.38 0.00 0.00 0.00 5, 811.48 5,905.21 5, 976.78 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3.00 3.00 3.00 3.01 0.00 5,998.94 6,092.67 6,186.40 6,280.14 6,373.87 6,467.60 6, 561.33 6,655.06 6,685.18 6,746.80 6,760.70 6,843.11 6,938.79 7,035.58 7,133.22 7,231.44 7,251.44 7.327.39 560,866.00 0.00 7,329.92 560,866.00 0.00 7,330.22 560,866.73 0.00 7,428.40 560,867.47 0.00 7,526.88 560,867.84 0.00 7,576.42 560,867.85 3.00 7,577.02 560,868.22 3.00 7,625.47 560,868.99 3.00 7,719.61 10/24/2006 4:11:28PM Page 6 of 10 COMPASS 2003.11 Burld 50 ~~ ~~ R ~ ~ ` • ~an©co~tllips Alaska Halliburton Energy Services Planning Report -Geographic C7 ti 4 Grilling and Formation Evaluation I~ Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 1 S (40+81) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81 )) i Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-136 Design: 1J-1~:8 r,=:a08) Planned Survey 1J-136 (wp08) Map Map MD -nclination Azimuth TVD SSTVD +NI-S +E/-W Northing Easting DLSEV Vert Section (ft1 (°) (°) (ft) (ft) (ft) (ft) (ft) lftl (°/100ft) (ft) 9,500.00 84.49 179.96 3,568.61 3,447.61 -7,724.71 1,877.72 5,937,668.57 560,869.03 2.98 7,724.71 9,516.85 85.00 179.95 3,570.15 3,449.15 -7,741.48 1,877.74 5,937,651.79 560,869.18 3.01 7,741.48 End DtR ~ 4517' MD, 3570' TVD 9,546.32 85.00 179.95 3,572.72 3,451.72 -7,770.85 1,877.76 5,937,622.43 560,869.43 0.00 7,770.85 9 5!8" Gsg -Began DlR 2.5°/100' @ 9546' MD, 3573' TVD: 92T FNL, 412' FEL - Sec1 1-T10N-R10E - 9 5/8" -1J-136 wp08 B Top 9,600.00 86.34 179.97 3,576.78 3,455.78 -7,824.37 1,877.80 5,937,568.92 560,869.89 2.50 7,824.37 9,700.00 88.84 180.01 3,580.99 3,459.99 -7,924.27 1,877.81 5,937,469.03 560,870.68 2.50 7,924.27 9,778.14 90.79 180.05 3,581.24 3,460.24 -8,002.41 1,877.77 5,937,390.90 560,871.26 2.50 8,002.41 End DIR ~ 9778' MD, 358 1' TVD 9,800.00 90.79 180.05 3,580.94 3,459.94 -8,024.27 1,877.76 5,937,369.04 560,871.41 0.00 8,024.27 9,900.00 90.79 180.05 3,579.56 3,458.56 -8,124.26 1,877.68 5,937,269.07 560,872.11 0.00 8,124.26 10,000.00 90.79 180.05 3,578.18 3,457.18 -8,224.25 1,877.60 5,937,169.09 560,872.82 0.00 8,224.25 10,100.00 90.79 180.05 3,576.80 3,455.80 -8,324.24 1,877.52 5,937,069.11 560,873.52 0.00 8,324.24 10,200.00 90.79 180.05 3,575.42 3,454.42 -8,424.23 1,877.44 5,936,969.13 560,874.23 0.00 8,424.23 10,297.66 90.79 180.05 3,574.07 3,453.07 -8,521.88 1,877.37 5,936,871.49 560,874.91 0.00 8,521.88 Geosteer in the B-Sand ~ 10298' MD, 3574' TVD 10,300.00 90.81 179.98 3,574.04 3,453.04 -8,524.22 1,877.37 5,936,869.15 560,874.93 3.00 8,524.22 10,306.15 90.86 179.80 3,573.95 3,452.95 -8,530.37 1,877.38 5,936,863.00 560,874.99 3.00 8,530.37 10,400.00 90.86 179.80 3,572.54 3,451.54 -8,624.21 1,877.70 5,936,769.18 560,876.05 0.00 8,624.21 10,500.00 90.86 179.80 3,571.04 3,450.04 -8,724.19 1,878.05 5,936,669.21 560,877.18 0.00 8,724.19 10,600.00 90.86 179.80 3,569.54 3,448.54 -8,824.18 1,878.40 5,936,569.23 560,878.32 0.00 8,824.18 10,700.00 90.86 179.80 3,568.04 3,447.04 -8,924.17 1,878.75 5,936,469.26 560,879.45 0.00 8,924.17 10,800.00 90.86 179.80 3,566.54 3,445.54 -9,024.16 1,879.10 5,936,369.29 560,880,58 0.00 9,024.16 10,900.00 90.86 179.80 3,565.04 3,444.04 -9,124.15 1,879.45 5,936,269.32 560,881.71 0.00 9,124.15 11,000.00 90.86 179.80 3,563.54 3,442.54 -9,224.14 1,879.80 5,936,169.34 560,882.84 0.00 9,224.14 11,100.00 90.86 179.80 3,562.04 3,441.04 -9,324.12 1,880.15 5,936,069.37 560,883.97 0.00 9,324.12 11,102.37 90.86 179.80 3,562.00 3,441.00 -9,326.49 1,880.16 5,936,067.00 560,884.00 0.00 9,326.49 1J-136 wp08 T2 11,121.98 91.29 180.20 3,561.63 3,440.63 -9,346.10 1,880.16 5,936,047.39 560,884.15 3.00 9,346.10 11,200.00 91.29 180.20 3,559.87 3,438.87 -9,424.10 1,879.89 5,935,969.41 560,884.49 0.00 9,424.10 11,300.00 91.29 180.20 3,557.62 3,436.62 -9,524.07 1,879.54 5,935,869.44 560,884.93 0.00 9,524.07 11,400.00 91.29 180.20 3,555.36 3,434.36 -9,624.05 1,879.19 5,935,769.48 560,885.36 0.00 9,624.05 11,500.00 91.29 180.20 3,553.10 3,432.10 -9,724.02 1,878.85 5,935,669.51 560,885.80 0.00 9,724.02 11,600.00 91.29 180.20 3,550.85 3,429.85 -9,823.99 1,878.50 5,935,569.55 560,886.24 0.00 9,823.99 11,700.00 91.29 180.20 3,548.59 3,427.59 -9,923.97 1,878.15 5,935,469.59 560,886.67 0.00 9,923.97 11,800.00 91.29 180.20 3,546.34 3,425.34 -10,023.94 1,877.81 5,935,369.62 560,887.11 0.00 10,023.94 11,900.00 91.29 180.20 3,544.08 3,423.08 -10,123.92 1,877.46 5,935,269.66 560,887.54 0.00 10,123.92 12,000.00 91.29 180.20 3,541.82 3,420.82 -10,223.89 1,877.11 5,935,169.69 560,887.98 0.00 10,223.89 12,100.00 91.29 180.20 3,539.57 3,418.57 -10,323.86 1,876.77 5,935,069.73 560,888.41 0.00 10,323.86 12,200.00 91.29 180.20 3,537.31 3,416.31 -10,423.84 1,876.42 5,934,969.77 560,888.85 0.00 10,423.84 12,300.00 91.29 180.20 3,535.06 3,414.06 -10,523.81 1,876.07 5,934,869.80 560,889.29 0.00 10,523.81 12,400.00 91.29 180.20 3,532.80 3,411.80 -10,623.79 1,875.73 5,934,769.84 560,889.72 0.00 10,623.79 12,500.00 91.29 180.20 3,530.54 3,409.54 -10,723.76 1,875.38 5,934,669.87 560,890.16 0.00 10,723.76 12,600.00 91.29 180.20 3,528.29 3,407.29 -10,823.73 1,875.03 5,934,569.91 560,890.59 0.00 10,823.73 12,700.00 91.29 180.20 3,526.03 3,405.03 -10,923.71 1,874.69 5,934,469.95 560,891.03 0.00 10,923.71 12,800.00 91.29 180.20 3,523.78 3,402.78 -11,023.68 1,874.34 5,934,369.98 560,891.46 0.00 11,023.68 10/24/2006 4:11:28PM Page 7 of 10 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic t Orilling and Formation Evaluation Database: _EDM_2003.11_b48 Locai Co-ordinate Reference: Well Plan 1J-136 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 ~ Design: 1J-136 (wp08) Planned Survey 1J-136 (wp08) Map Map MD I nclination Azimuth TVD SSTVD +NiS +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft} (ft) (ft) (ft) (ft) (°1100ft} Ift) 12,900.00 91.29 180.20 3,521.52 3,400.52 -11,123.66 1,873.99 5,934,270.02 560,891.90 0.00 11,123.66 12,923.03 91.29 180.20 3,521.00 3,400.00 -11,146.68 1,873.91 5,934,247.00 560,892.00 0.00 11,146.68 1J-136 wp08 T3 12,926.72 91.31 180.09 3,520.92 3,399.92 -11,150.37 1,873.90 5,934,243.31 560,892.02 3.00 11,150.37 13,000.00 91.31 180.09 3,519.24 3,398.24 -11,223.63 1,873.79 5,934,170.05 560,892.48 0.00 11,223.63 13,100.00 91.31 180.09 3,516.94 3,395.94 -11,323.60 1,873.63 5,934,070.09 560,893.10 0.00 11,323.60 13,200.00 91.31 180.09 3,514.65 3,393.65 -11,423.58 1,873.47 5,933,970.13 560,893.73 0.00 11,423.58 13,300.00 91.31 180.09 3,512.36 3,391.36 -11,523.55 1,873.32 5,933,870.17 560,894.35 0.00 11,523.55 13,400.00 91.31 180.09 3,510.07 3,389.07 -11,623.52 1,873.16 5,933,770.21 560,894.98 0.00 11,623.52 13,500.00 91.31 180.09 3,507.77 3,386.77 -11,723.50 1,873.00 5,933,670.24 560,895.61 0.00 11,723.50 13,600.00 91.31 180.09 3,505.48 3,384.48 -11,823.47 1,872.85 5,933,570.28 560,896.23 0.00 11,823.47 13,700.00 91.31 180.09 3,503.19 3,382.19 -11,923.44 1,872.69 5,933,470.32 560,896.86 0.00 11,923.45 13,800.00 91.31 180.09 3,500.90 3,379.90 -12,023.42 1,872.53 5,933,370.36 560,897.48 0.00 12,023.42 13,900.00 91.31 180.09 3,498.60 3,377.60 -12,123.39 1,872.38 5,933,270.40 560,898.11 0.00 12,123.39 14,000.00 91.31 180.09 3,496.31 3,375.31 -12,223.37 1,872.22 5,933,170.43 560,898.73 0.00 12,223.37 14,100.00 91.31 180.09 3,494.02 3,373.02 -12,323.34 1,872.06 5,933,070.47 560,899.36 0.00 12,323.34 14,200.00 91.31 180.09 3,491.73 3,370.73 -12,423.31 1,871.90 5,932,970.51 560,899.98 0.00 12,423.31 14,300.00 91.31 180.09 3,489.43 3,368.43 -12,523.29 1,871.75 5,932,870.55 560,900.61 0.00 12,523.29 14,362.57 91.31 180.09 3,488.00 3,367.00 -12,585.84 1,871.65 5,932,808.00 560,901.00 0.00 12,585.84 1J-136 wp08 T4 14,375.43 90.98 180.28 3,487.74 3,366.74 -12,598.70 1,871.61 5,932,795.14 560,901.06 3.00 12,598.70 14,400.00 90.98 180.28 3,487.32 3,366.32 -12,623.26 1,871.49 5,932,770.58 560,901.13 0.00 12,623.26 14,500.00 90.98 180.28 3,485.62 3,364.62 -12,723.25 1,871.00 5,932,670.61 560,901.43 0.00 12,723.25 14,600.00 90.98 180.28 3,483.91 3,362.91 -12,823.23 1,870.51 5,932,570.63 560,901.72 0.00 12,823.23 14,700.00 90.98 180.28 3,482.21 3,361.21 -12,923.22 1,870.03 5,932,470.65 560,902.02 0.00 12,923.22 14,800.00 90.98 180.28 3,480.50 3,359.50 -13,023.20 1,869.54 5,932,370.68 560,902.31 0.00 13,023.20 14,900.00 90.98 180.28 3,478.79 3,357.79 -13,123.18 1,869.05 5,932,270.70 560,902.61 0.00 13,123.18 15,000.00 90.98 180.28 3,477.09 3,356.09 -13,223.17 1,868.56 5,932,170.73 560,902.90 0.00 13,223.17 15,100.00 90.98 180.28 3,475.38 3,354.38 -13,323.15 1,868.07 5,932,070.75 560,903.20 0.00 13,323.15 15,200.00 90.98 180.28 3,473.68 3,352.68 -13,423.14 1,867.59 5,931,970.78 560,903.49 0.00 13,423.14 15,300.00 90.98 180.28 3,471.97 3,350.97 -13,523.12 1,867.10 5,931,870.80 560,903.78 0.00 13,523.12 15,400.00 90.98 180.28 3,470.26 3,349.26 -13,623.11 1,866.61 5,931,770.83 560,904.08 0.00 13,623.11 15,500.00 90.98 180.28 3,468.56 3,347.56 -13,723.09 1,866.12 5,931,670.85 560,904.37 0.00 13,723.09 15,600.00 90.98 180.28 3,466.85 3,345.85 -13,823.07 1,865.64 5,931,570.88 560,904.67 0.00 13,823.07 15,700.00 90.98 180.28 3,465.14 3,344.14 -13,923.06 1,865.15 5,931,470.90 560,904.96 0.00 13,923.06 15,800.00 90.98 180.28 3,463.44 3,342.44 -14,023.04 1,864.66 5,931,370.92 560,905.26 0.00 14,023.04 15,900.00 90.98 180.28 3,461.73 3,340.73 -14,123.03 1,864.17 5,931,270.95 560,905.55 0.00 14,123.03 16,000.00 90.98 180.28 3,460.03 3,339.03 -14,223.01 1,863.69 5,931,170.97 560,905.85 0.00 14,223.01 16,100.00 90.98 180.28 3,458.32 3,337.32 -14,323.00 1,863.20 5,931,071.00 560,906.14 0.00 14,323.00 16,200.00 90.98 180.28 3,456.61 3,335.61 -14,422.98 1,862.71 5,930,971.02 560,906.44 0.00 14,422.98 16,300.00 90.98 180.28 3,454.91 3,333.91 -14,522.96 1,862.22 5,930,871.05 560,906.73 0.00 14,522.96 16,400.00 90.98 180.28 3,453.20 3,332.20 -14,622.95 1,861.74 5,930,771.07 560,907.03 0.00 14,622.95 16,500.00 90.98 180.28 3,451.50 3,330.50 -14,722.93 1,861.25 5,930,671.10 560,907.32 0.00 14,722.93 16,600.00 90.98 180.28 3,449.79 3,328.79 -14,822.92 1,860.76 5,930,571.12 560,907.62 0.00 14,822.92 16,700.00 90.98 180.28 3,448.08 3,327.08 -14,922.90 1,860.27 5,930,471.15 560,907.91 0.00 14,922.90 16,800.00 90.98 180.28 3,446.38 3,325.38 -15,022.89 1,859.78 5,930,371.17 560,908.21 0.00 15,022.89 16,900.00 90.98 180.28 3,444.67 3,323.67 -15,122.87 1,859.30 5,930,271.20 560,908.50 0.00 15,122.87 17,000.00 90.98 180.28 3,442.97 3,321.97 -15,222.85 1,858.81 5,930,171.22 560,908.80 0.00 15,222.85 10/24/2006 4:11:28PM Page 8 of 10 COMPASS 2003.11 Build 50 ~:. _ ;~~: • • i CanacQPhilf~ps AI3S{Cc3 Halliburton Energy Services ~ _ Planning Report -Geographic Grilling and Formation Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-136 Company; ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore; 1J-136 Design: 1J-136 (wp08) Planned Survey 1J-;~sa ~;wp08) Map MD Inclination Azimuth TVD SSTVD +N/-S +E1-W Northing (ft) (°) (°) (ftt (ft) (ft- (ft) (ft) 17,100.00 90.98 180.28 3,441.26 3,320.26 -15,322.84 1,858.32 5,930,071.24 17,200.00 90.98 180.28 3,439.55 3,318.55 -15,422.82 1,857.83 5,929,971.27 17,300.00 90.98 180.28 3,437.85 3,316.85 -15,522.81 1,857.35 5,929,871.29 17,400.00 90.98 180.28 3,436.14 3,315.14 -15,622.79 1,856.86 5,929,771.32 . 17,408.00 90.98 180.28 3,436.01 3,315.01 -15,630.79 1,856.82 5,929,763.32 41/2" 17,408.32 90.98 180.28 3,436.00 ~ 3,315.00 -15,631.11 1,856.82 5,929,763.00 BHL 17408' MD, 3436` TVD: 1773' FSL, 441' FEL - Sec14-T10N-R10E - 1J-136 wp08 B Toe Map Fasting DLSEV Vert Section (ft~ (°1100ft) (ft) 560,909.09 0.00 15,322.84 560, 909.39. 0.00 15,422.82 560,909.68 0.00 15,522.81 560,909.98 0.00 15,622.79 560,910.00 0.00 15,630.79 560,910.00 0.00 15,631.11 Geologic Targets 1J-136 TVD (ff} 3,562.00 - Point 3,488.00 - Point 3,436.00 - Point 3,521.00 - Point 3,572.72 - Point 3,505.00 - Point Target Name +N/-S +E/-W Northing Fasting -Shape ft ft (ft) (ft) 1J-136 wp08 T2 -9,326.49 1,880.16 5,936,067.00 560,884.00 1J-136 wp08 T4 -12,585.84 1,871.65 5,932,808.00 560,901.00 1J-136 wp08 B Toe -15,631.11 1,856.82 5,929,763.00 560,910.00 1J-136 wp08 T3 -11,146.68 1,873.91 5,934,247.00 560,892.00 1J-136 wp08 B Top -7,770.85 1,877.76 5,937,622.43 560,869.43 1J-136 wp08 D Top -7,330.22 1,877.78 5,938,063.00 560,866.00 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft? (ft) (,.) (..~ 9,546.32 3,572.72 9-6/8 12-1/4 17,408.00 3,436.01 4-1/2 6-3/4 3,588.53 2,197.17 13-3/8 16 10/24/2006 4:11:28PM Page 9 of 10 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska Database: _EDM_2003.11_tvi8 Local Co-ordinate Reference: Well Plan 1J-136 ~~ Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) 'i Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) ~ Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Wellbore: 1J-136 Design: 1J-136 (wp08) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N!-E +E/-W (ft) (°) (°) (ft) (~) (ftl Name 1,619.97 44.03 164.98 1,514.00 -397.55 106.67 Permafrost 1,831.37 49.67 164.98 1,662.00 -543.20 145.75 K15 2,711.68 76.04 164.98 1,985.62 -1,323.29 355.03 T3 3, 588.54 76.04 164.98 2,197.17 -2,145.19 575.52 T3+550 6,544.80 76.04 164.98 2,910.40 -4,916.15 1,318.87 Ugnu C 7,404.95 76.04 164.98 3,117.92 -5,722.38 1,535.15 Ugnu B 7,676.36 76.04 164.98 3,183.40 -5,976.78 1,603.40 Ugnu A 8,432.13 76.04 164.98 3,365.74 -6,685.18 1,793.44 K13 9,097.43 80.00 180.02 3,504.50 -7,327.39 1,877.78 West Sak D 9,350.92 80.02 180.02 3,548.52 -7,577.02 1,877.69 West Sak C 9,494.88 84.34 179.96 3,568.11 -7,719.61 1,877.72 WestSak6 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W Comment (ft) ift) ift} (ftj 40.00 40.00 0.00 0.00 SHL: 1564' FSL, 2282' FEL -Sec 35-T11 N-R10E 400.00 400.00 0.00 0.00 KOP -Begin Dir 2.5°/100' @ 400' MD, 400' TVD 713.98 713.00 -20.74 5.57 Continue Dir 4°/100' @ 714' MD, 713' TVD 1,618.58 1,513.00 -396.62 106.42 End Dir @ 1619' MD, 1513' TVD 1,718.58 1,584.89 -463.75 124.44 Begin DIR 5°/100' @ 1719' MD, 1585' TVD 2,358.69 1,900.46 -992.43 266.27 End DIR @ 2359' MD, 1900' TVD 3,588.53 2,197.17 -2,145.18 575.52 13 3/8" Csg - 3589' MD, 2197' TVD: 581' FNL, 1709' FEL -Sect-T10N-R10E 8,512.70 3,385.18 -6,760.70 1,813.69 Begin DIR 3°/100' @ 8513' MD, 3385' TVD 9,020.31 3,491.11 -7,251.44 1,877.80 End DIR @ 9020' MD, 3491' TVD 9,350.31 3,548.41 -7,576.42 1,877.69 Begin DIR 3 °/100' @ 9350' MD, 3548' TVD 9,516.85 3,570.15 -7,741.48 1,877.74 End DIR @ 9517' MD, 3570' TVD 9,546.32 3,572.72 -7,770.84 1,877.76 9 5/8" Csg -Begin DIR 2.5°/100' @ 9546' MD, 3573' TVD: 927' FNL, 412' FEL - Sec11= 9,778.14 3,581.24 -7,770.84 1,877.76 End DIR @ 9778' MD, 3581' TVD 10,297.66 3,574.07 -8,002.41 1,877.77 Geosteer in the B-Sand @ 10298' MD, 3574' TVD 17,408.32 3,436.00 -8,521.88 1,877.37 BHL 17408' MD, 3436' TVD: 1773' FSL, 441' FEL - Sec14-T10N-R10E Halliburton Energy Services Planning Report -Geographic • _~ Drilling and Formation Evaluation 10/24/2006 4:11:28PM Page 10 of 10 COMPASS 2003.11 Build 50 .. s.. t ~- • ConocoPhillips Alaska Plan: 1J-136 (wp08) ~J Sperry Drilling Services Anticollision Summary 25 October, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-136 1 J-136 Local Coordinate Origin: Centered on Well Plan 1J-136 Viewing Datum: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet I .... ~..,, __ ,.~ ~.~ .T, ... ~... __~ .. _ _ . _ _ _ ~ _ _. , _, ,.~ _._ .. ~, a.. ~ ...~ _ . ,._ . ~ .... _ . „ ~ .. ., ,.., _ ~ , Sperry Drilling Services ORIGINAL qC Y ~ L" 0 a z Z~ 'E ~ 2 V C V H Z ~tanV~~ o °rE3i$m C V A._ - C y~ N r W K 0 O1 °o E °o u °o J Wt. h .. 'C t. -c ~w~H~ w °o~`oO1 0 Y .W V/W ~ z 3 a a f U N v3 ~r J ~- a euZ e a .o G mRm w ~? v J ~ ~ J 3 O a ~ aro ~ oc~ N ~ a n Wm a h ~ a c °u, t~ zn 30 ~o z°e 0 e <a m°o t9 -°nro3 Z ~~ i~ m Z COq' N - ' ~ ~ r C w E v '° J 9LLCa O G v ~ w U W ~ ~ d z c¢ E:! oc- c a~¢ g~ c 0 m y ~i y tih l as ~~ Y1 yaa ~ t~a~. 4 F~~EE ~44Y d~~~ C i i i E = ~ '~'~ =~~ E$$v t°g~ O c i a ~\ ~o ~41~ C ~ ~ ~ i ~ ~ i N ~ ~ ~ 3 ~'' ,~~ ~ ~ I i ~ i / ~ I ~ I ~ W ~ ~ ~ r can ~ d ~ ~ ~ d ~ 3 0 3 N eh 7 \\\ .5 ~ a O C q $ Y g ~p '.,° 8 '~° R X R ~ i i i i i i a ~ ~ ssasc~a,~.a.ae~m~.a~^.e.a~a~z °R88g°~~~~~8mmw~SA~~~ 9 U 8°~sOes.ss8.ms.x.a~s.e.s.~s~s LLoo~e ~ ageoo.eee~ego F eu ~ y ~, sssass.s.sssas,sas.s.s.s.s.ss.as. w h a ~ ie8ng$n c.~~e~~~~°°°: x, e,e: loan"r:cEEEmmEEgmmmmmm y w ^ o ~ 4 aam~~~~_ w ~~~~w ~588$~Y~z8:~E. YySa8r8w8 ~_8 s~n$:~Sc~~~a~~~~~~~aa ~'. s 8 Smm««ee~~ ~=8szaii~°m~~°ma-sus==s -oe~`sa~~mmm:m:saa::e:axa 7 ~s.s.~~~a~.~.~~;y~yse~s«.s~~:~ Ste'. ~«m&$$~&:WR°~aa~~S a, U ~~~~.e,.~ma..~~~_~~~~~..r~ .; to F o~ S~ o 8° o S~ 8° S° S ~~~ N~ m~~~ ~ n n m aNO m m rn O ~O I II I I II I I I III I I I;I ~p U 0 0 0 0 0 0 0 0 p 0 0 p 0p 0 p 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0o 0 0 0 p 0 0 0 0 N N~ r S~ N n S N ~l1 n S N h r O N~ r O N~ I~ O N N r O N N r S N N r E ~ ~ ~ N N N N th M M M Q C Q 7~ N W~ W W N (O n r n n t0 W m m d O c .~ M o. n ~~ o -i ~~~ - ~~ \`~ ~1\ \` ~ ~ \\~ r \~ °w "c i ~ - ~i i r 0 ~!~_"~11 _; - ,,, ~~' - ~.- ro o ~ q ~~~~~.~: ~.} ~ 0 N C V 00 C d L F S $ 0 0 0 0 O O C~ Zr r F~W ~~ 2 ~ ~ ~ ~ ~ O '==.v ggo°-oE OLL SGN~~ z W W L d d 9 U C C C C r Z m K `v d ~ W CKKKp C W O Nt. m ~ ~ ~ ~ ~ '° O w V ~ ~ N H g; V ~ CortcxoE~~fl~ps F~la~ Halliburton Energy Services Anticollision Report ins Drilling and Formation Evaluation Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-136 Project: Kuparuk River Unit TVD Reference: Doyon 15 (40+g1) @ 121 OOft (Doyon 15 (40+81)) Reference Site: Kuparuk 1J Pad MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-136 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-136 Database: _EDM_2003.11_b48 Reference Design: 1J-136 (wp08) Offset TVD Reference: Offset Datum Reference 1J-136 (wp08) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,940.83ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program From (ft} 40.00 1,350.00 379.53 Date 10:2412006 To (ft) Survey (Wellbore) 1,350.00 1J-136 (wp08) (1J-136) 3,579.53 1J-136 (wp08) (1J-136) 17,408.32 1J-136 (wp08) (1J-136) Tool Name CB-GYRO-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Description Camera based gyro single shot MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC CC -Min cenfre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation SOf25620Q& s~_36:54PM Page 2 of 3 COMPASS 2003. ?? Build 50 ORIGINAL ConocoPhillips Alaska Halliburton Energy Services Anticollision Report ~.~.t Criiling and Formation Evaluation Company; ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-136 ~~ Project: Kuparuk River Unit ND Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Reference Site: Kuparuk 1J Pad MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+g1)) i Site Error: O.OOft Reference Well: Well Error: Reference Wellbore Reference Desiyn: Plan 1J-136 O.OOft 1J-136 1 J-136 (wp08) North Reference: Survey Calculation Method Output errors are at Database: Offset TVD Reference: True Minimum Curvature 2.00 sigma _E D M_2003.11 _b48 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 Weli -Wellbore -Design (ft) (R) (ft) (ft) Kuparuk 1J Pad 1 J-127 - 1 J-127 - 1 J-127 446.34 450.00 181.10 9.45 171.65 Pass -Major Risk 1J-127 - 1J-127 L1 - 1J-127 L1 Rig Surveys 446.34 450.00 181.10 9.45 171.65 Pass -Major Risk 1J-127 - 1J-127 L1 P61 - 1J-127 L1 PB1 Rig Surveys 446.34 450.00 181.10 9.45 171.65 Pass -Major Risk 1J-127 - 1J-127 P61 - 1J-127 PB1 Rig Surveys 446.34 450.00 181.10 9.40 171.70 Pass -Major Risk 1 J-127 - 1 J-127 PB2 - 1J-127 PB2 Rig Surveys 446.34 450.00 181.10 9.40 171.70 Pass -Major Risk 1J-14 - 1J-14 - 1J-14 1,569.68 1,550.00 57.96 32.57 27.62 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 430.11 425.00 539.04 9.23 529,81 Pass -Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 430.11 425.00 539.04 9.23 529.81 Pass -Major Risk 1 J-184 - 1J-184 - 1 J-184 436.94 425.00 146.84 9.37 137.47 Pass -Major Risk 1J-184 - 1J-184 L1 - 1J-184 L1 436.94 425.00 146.84 9.37 137.47 Pass -Major Risk Plan 1 J-103 - 1 J-103 - 1 J-103 (wp06) 386.99 375.00 680.70 8.10 672.60 Pass -Major Risk Plan 1 J-124 -Plan 1 J-124 - 1 J-124 (wp02) 580.39 600.00 236.20 12.61 223.60 Pass -Major Risk Plan 1 J-130 -Plan 1 J-130 - 1 J-130 (wp02) 518.56 525.00 119.32 11.15 108.17 Pass -Major Risk Plan 1 J-133 - 1 J-133 - 1 J-133 (wp06) - D141 655.28 650.00 55.05 14.14 40.95 Pass -Major Risk Plan 1 J-133 - 1 J-133 - 1 J-133 Intermediate 654.89 650.00 45.84 14.37 31.50 Pass -Major Risk Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) 667.53 675.00 46.12 14.67 31.48 Pass -Major Risk Plan 1 J-135 -Plan 1 J-135 - 1 J-135 (wp02) 449.56 450.00 20.55 8.33 12.22 Pass -Major Risk Plan 1J-135 -Plan 1J-135 L1 - 1J-135 L1 (wp02) 449.56 450.00 20.55 8.33 12.22 Pass -Major Risk Plan 1J-136- 1J-136 L1 - 1J-136 L1 (wp08) 9,124.99 9,125.00 0.64 0.70 -0.06 FAIL- No Errors Plan 1 J-176 (Q2 Phase 2) - 1 J-176 - 1 J-176 (wp01 410.96 400.00 217.66 8.75 208.91 Pass -Major Risk Plan 1 J-176 (Q2 Phase 2) - 1 J-176 - 1 J-176 wp02 434.48 425.00 217.35 9.26 208.09 Pass -Major Risk Plan 1 J-176 (02 Phase 2) - 1 J-176 L1 - 1 J-176 L1 434.48 425.00 217.35 9.26 208.09 Pass -Major Risk Plan 1 J-176 (Q2 Phase 2) - 1 J-176 L1 - 1 J-176 L1 410.96 400.00 217.66 8.75 208.91 Pass -Major Risk Plan 1 J-178 (Q3 Phase 2) - 1 J-178 L1 - 1 J-178 L1 399.73 400.00 190.41 8.53 181.87 Pass -Major Risk Plan 1J-178 (Q3 Phase 2) -Plan 1J-178 - 1J-178 399.73 400.00 190.41 8.53 181.87 Pass -Major Risk Plan 1 J-180 -Plan 1 J-180 - 1 J-180 (wp08) 424.08 425.00 167.55 9.06 158.48 Pass -Major Risk Plan 1 J-180 -Plan 1 J-180 L1 - 1 J-180 L1 (wp08) 424.08 425.00 167.55 9.06 158.48 Pass -Major Risk Rig: 1J-102 - 1J-102 - 1J-102 7,695.45 11,025.00 609.15 225.66 468.17 Pass -Major Risk Rig: 1J-102 - 1J-102 L1 - 1J-102 L1 8,833.90 12,242.00 219.35 32.57 203.33 Pass -Minor 1/200 Rig: 1J-102 - 1J-102 L2 - 1J-102 L2 8,334.39 11,775.00 202.48 33.87 169.80 Pass -Minor 1/200 Rig: 1J-102 - 1J-102 L2 P62 - 1J-102 L2 P62 6,305.55 9,599.00 827.45 194.93 682.72 Pass -Major Risk Rig: 1J-102 - 1J-102 P63 - 1J-102 PB3 249.99 250.00 700.74 5.11 695.63 Pass -Major Risk Rig: 1J-137 - 1J-137 - 1J-137 Rig 311.99 300.00 20.94 6.58 14.37 Pass -Major Risk Rig: 1J-137 - 1J-137 L1 - 1J-137 L1 311.99 300.00 20.94 6.58 14.37 Pass -Major Risk Rig: 1J-137 - 1J-137 L1 PB1 - 1J-137 L1 PB1 311.99 300.00 20.94 6.58 14.37 Pass -Major Risk Rig: 1J-137 - 1J-137 L1 P62 - 1J-137 L1 PB2 311.99 300.00 20.94 6.58 14.37 Pass -Major Risk Rig: 1 J-182 - 1 J-182 - 1 J-182 473.52 475.00 149.42 10.02 139.40 Pass -Major Risk Rig: 1J-182 - 1J-182 L1 - 1J-182 L1 (wp13) 424.49 425.00 152.88 9.07 143.81 Pass -Major Risk Rig: 1J-182 - 1J-182 PB1 - 1J-182 Rig 473.52 475.00 149.42 10.02 139.40 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 467.53 475.00 223.53 13.43 210.11 Pass -Major Risk WSP-08 -WSP-08 -WSP-08 459.78 450.00 166.44 18.20 153.16 Pass -Major Risk WSP-09 -WSP-09 -WSP-09 470.92 475.00 106.65 11.66 95.00 Pass -Major Risk WSP-10 -WSP-10 -WSP-10 440.24 425.00 55.98 10.31 45.67 Pass -Major Risk WSP-11 -WSP-11 -WSP-11 749.41 750.00 33.80 17.47 16.33 Pass -Major Risk WSP-12 -WSP-12 -WSP-12 982.22 975.00 34.94 10.70 24.23 Pass -Minor 1/200 WSP-13 -WSP-13 -WSP-13 1,135.53 1,100.00 27.95 9.26 18.69 Pass -Minor 1/200 WSP-14 -WSP-14 -WSP-14 1,284.67 1,250.00 32.25 10.95 21.31 Pass -Minor 1/200 CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 10/25/2006 5:36:54PM Page 3 of 3 COMPASS 2003.11 Build 50 ~ U [~ C VI Y Y Y O ~ ~~ ~ ~~ma ~~n~ F E~~ } C C C M N N N o i°aYi ~»>Y~~~ O LhhCO~ONtOMMN00 ~QIMIO In W OMr~O00 f- aOrr00~~tDNhOt7 Z QtO OOh~~i'h c0 '.tOM V Q ~rrNMC0hhc001OO Q L O O N~ O N O C' O N r OOtD aO~thO~r aMr~tD 07 tD Nl~Mh h Q.' Qf d'tChMOtD d'OONq~ Q OMOOOOhTONM~ V L 1. ? r r r N N N M M M M M FO ZrNM V OCOhCOO~r L >aM~C ~~~~ 3 ~ .... ~ Y ~ ~ ~ ~ = l^7 ~ ~ ~ ~ r Q Qa L ~ Q YY_~r r ~~ ~~~ R .,N a 0 L ~. N ~ N M N_1{yrM fn01~r d' _~ J ~ ~ r M ~ ZO»~ W ~ ~rNi°o~ C7 co ao ao Z ~°vv00i a a>i.M r U ~ ti O r ti M ~ M M N Z r N M ~~ ~ ~O O 0 O o0 0 o ~ ~ o0 0 a v O 3 a J 3 ~ ~ 0 0 ~ ~ ~ ~~ 0 ~` 0 '~ ~ ,I 0 ~ ._ ~-., , . ,I ,I I ~ I N \ 0 ~ N _ O J J `! I ~ ~ ~ O av I.. r ~ O \ O I ~ ~ 2 =.i ~ 3 O I I f ~ th ~ I O i I ~ ~ ~ / ~/ \ X M i ~ i ~~V// ~„ /// ~ ~ \ M ~ i N r N O / ~ 0' N O .'- ~ 3 a J __- ' 3 __._ ~ / / ~ N ~ \ J ~' I / r / ~ - / ~ ~-- i _ ~ J ~ '. ~, ------------ ._ a ., 3 m ~ ~ a , J d r~ ~ 3 ~ ~ ,~ ~ ~ ~ ~ m a J / I n r~ ~ T J ~ ti / r ~ h O -/' O O ~ ° ~ 0 0 0 O n °o l °o o, ORIGINAL Closest in POOL ~, ClosestA roach: Reference Well: 1J-136 w 08 Plan Offset Well: 1J-102 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' ' Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E +)/W -) 180°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (686.1 ft) in POOL (686.1 ft) in POOL (9494.88 - 17408.32 (9494.88 - 17408.32 MD) to 1J-136 (wp08) MD) to 1J-102 L1 Plan (5185.45 - 686.1 9494.88 84.34 179.96 3447.052 5937673.1 560869.7 7719.525 (5185.45 - 12242 MD) 12242 91.34 177.58 3461.476 5938331.2 560676.5 7059.843 12242 MD) Closest A roach: Reference Well: 1J-136 w 08 Plan Offset Well: 1J-135 w 02 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments POOL Min Distance POOL Min Distan (1210.48 ft) in POOL (1210.48 ft) in PO (9494.88 - 17408.32 (9494.88 - 17408.32 MD) to 1J-135 (wp02) MD) to 1J-136 (wp08) (8219.23 - 15043.58 Plan (8219.23 - 1210.48 14150 91.31 180.09 3371.979 5933019.4 560900.5 12373.24 MD) 15043.58 91.48 180.41 3412.815 5933016.3 562110.2 12385.86 15043.58 MD) Closest A roach: Reference Well: 1J-136 w 08 Plan Offset Well: 1J-137 Ri Coords. - Coords. - ASP ASP 3-D ctr-cV Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS in. Dist Depth Incl. Angle TRUE Azi. TVD E(+ /W(-) (180° Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (1068.99 ft) in POOL (1068.99 ft) in POOL (9494.88 - 17408.32 (9494.88 - 17408.32 MD) to 1J-136 (wp08) MD) to 1J-137 Rig Plan (9250.07 - 1068.99 12000 91.29 180.2 3420.809 5935168.9 560888.7 10223.81 (9250.07 - 17386 MD) 11696.96 90.34 180.42 3387.897 5935162.8 559820.3 10221.51 17386 MD) POOL Summary136.x1s 10/2412006 3:15 PM 1~-136+~rilli (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS). Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and .Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Intermediate Hole Hazard Risk Level Miti ation Strate Running Sands grid Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA,. decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in outs backreamin 1J-136 Drilling Hazards Summary 10/24/2006 7:22 AM .. CemCADE Preliminary Jab Design 13 318n Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 10/12/2006 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface t` Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,619'MD(1,513'TVD) < Top of Tail at 2,788' MD < 13 3!8", 72.0# casing in 16" OH TD at 3,588' MD (2,195' TV D) Mark of Schlumberger 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 2,788' MD. Lead Slurry Minimum pump time: 270 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1619' - 80') x 3.50 (250% excess) = 2265.6 ft3 0.4206 ft3/ft x (2788' - 1619') x 1.35 (35% excess) = 663.8 ft3 81.5 ft3 + 2265.6 ft3+ 663.8 ft3 = 3010.9 ft3 3010.9 ft3 / 4.45 ft3/sk = 676.6 sks Round up to 680 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slum Minimum pump time: 190 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3588' - 2788') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 48~, Estimated BHCT = 64~. (BHST calculated using a gradient of 2.6/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (min) CW 100 5.0 10.0 2.0 2.0 Pressure Test 0.0 0.0 10.0 12.0 CW 100 5.0 40.0 8.0 20.0 Drop Bottom Plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 536.2 76.6 109.9 DeepCRETE 6.0 92.9 15.5 125.4 Drop Top Plug 0.0 0.0 5.0 130.4 Water 5.0 20.0 4.0 134.4 Switch to rig pump 0.0 0.0 5.0 139.4 Mud 7.0 495.2 70.7 210.1 Mud 3.0 10.0 3.3 213.4 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, Tv < 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. • ~ CemCADE Preliminary Job Design 9.625" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska,. Inc. Revision Date: 10/26/2006 Prepared by: Maureen Torrie Location: Anchorage, AK ~, Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 13 3/8", 72.0# casing at 3,589' MD < Top of Tail at 6,045' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 9,546' MD (3,573' ND) Schlumberger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 800' MD above target - (3460' MD annular length). Tail Slurry Minimum thickening time: 260 min. (Pump time plus 90 min.) DeepCRETE ~ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x (9546'-6045') x 1.25 (25% excess) = 1,370.6 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1370.6 ft3 + 34.1 ft3 = 1404.7 ft3 1388.7 ft3/ 2.25 ft3/sk = 624.3 sks Round up to 630 sks BHST = 83`F, Estimated BHCT = 61 ~. (BHST calculated using a gradient of 2.6/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Stage Time Cumulative Volume Time (bbll (min) (min) CW100 5.0' 10.0 2.0 10.0 Pressure Test 0.0 0.0 10.0 12.0 CW 100 5.0 40.0 8.0 20.0 Drop Plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 5.0 252.5 50.5 90.5 Drop Plug 0.0 0.0 5.0 95.5 Water 5.0 20.0 4.0 99.5 Switch to rig pump 0.0 0.0 5.0 104.5 Mud 6.0 680.0 113.3 217.8 Slow to Pump 3.0 15.0 5.0 222.8 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: 11.0 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Tubing, Special Drift to *I- 500' MD DB Nipple, set at +l- 500' MD ~ /GLM, Camco, 4712" x t" KBMG GLM, Cameo, 41/2" x 1" KBMG 13-118" Casinp Shoe, , 688, L-80, BTC set ~ 3589' MO, 2197' ND , CMD Sliding Sleeve, wl DB Nipple Tubing String / ~°•` 4112" 12.6y, L-80, IBTM ~, 3.958" ID, 3.833" Drift Loeatlng Ser Assembly 4.7s° ser oD r• x e-ms° txP Dner Top Packer _ _ _ -. - - wIM Hdd Downs • ~ .. Casing swbore f 4.76"ID Later al E nt rv M o d ule (LEMI ~~ e C Q ~ ~' ` _ 7"XAssembi PLinerTOp Packer with Hdd Downs ' 7.500" Tieback ExL ID 6.278" Tool Body ID -- Casing Serbore RecepWde ' 4.75" ID, 5.75" OD 20' Length Orienting Profile Automatic Alignment of LEM -- Positive Latching CdNt Indicates Correct Location \ ~- Seal Bore for Lrerel Isolation - 3.688" ID \ - Access Window Positive Lateral Access Via ~ ~ Thru-Tubing Divertar Seal Bore for Lateral Isolation - 3.888" ID Isolation Seal Asamdy d.75" Seal OD 7.875" gar ID 2' Lengtfl Latarr Enlry MadWe1LEM) Onantlrrg ProNe ConocoPhillips 1 J-136 West Sak 9-5/8" Intermediate Dual Lateral Injector B-aand Window 'D' Sand Lateral at 8100' MD, 7505' ND 5112" 16.69, Hydrll 6-1/2" 16.69, BTC, 621. L-80 Slonad LIMr L20 91ottW Liner 5.112" PayZona ECP Every OMer Jdnt Every OMer Jdnt .... Baker Oil Tools As Planned Lateral Entrv Module (LEMI With Diverters and Isolation Latew aaa.sa mverter Larorr 16aanan DiYeHer G9 RunnMg Tod 9mng InsWetl Ins[Wed (3.00" Labrr DnRI (L60" ID Mrnbore Dn1I) t- i 'G9'ProMefor -'--- CoN COMactor f Runnln9/Remeving ~)~ ~I ~ (t.w'LenpM) 1 ~ '~ j ~ snap lnlBnap OUt ~ I f Poaltlve LoulYrg~ -- Back Pressure Vrv (1.80' LengM) ~ Ca9N p~ .. 1 ~ ~' Laterr lsd.ean ~'r!"R I ~ flot.Tnrv9vnw H 1! ser: ~ j (1.26 Len9M) - H tlraWk ~ / Labrr Dlverler Ra ~ ~ y Disconnect - mp IWatloN Mambon ~; I ` . f (1.60'LangM) . ; ~. mwr1.r 31eeva 7~ _ GS SPear ~ ~ (1.60' Len9M) Lahrr Isolalbn , d86 R Approi OAL' _ s.rs '~ ,; ~ 'Jars may a required In highly deNatad 19' Dlverter LsngM 19' Sleeve LengM or deep appllutlons (B' approx langety. + 6-112" %9-618" Modal'B' HOOK Hancer: (PZ Rewap Ser Bare 3.68"ID 4112" 1289 Tublr 1.833" DHR 3.968"ID 7" Lln Liner Hangar I Packer Asse r ~ +I. 9200' MD \~-' ' Me 6-112" Gultla Slave 61/2" Casing Shoe, 15.St, L-80 BTCM 11Y Mnt joint shoo Sat ~ 17101' MD, 3373' ND 7" Tieback SNew -"- 3.682" DB Nlppla -_ ~-- --- ?. Z Ser Assamtly 176" Ser OD 3.676"ID 'B' Sand Lateral 6-112" 16.68, HydrY 6-112" 16.68, BTC, ]" x 9-618" fie. Lock 621, L-80 Slotted LIMr L-80 Sloted l1Mr Liner Hanper \ Every OMer Jdnt Every OMer Jdnt 6_112- Eceenme / Galae ah« ~/ Casing Serhora RecapMrJe ~ \t - w :-,. ' -~~~~• 5.1/2" Casing Shoe, SIB" O.Of, L-80 BTC Sat ~ 17408' MD, ~ 9548' MD, 3573' ND (84 deg inc) J Baker Hu9hea 1006. Tnia decumanr maY nor be reproduced ar dlalriburad, in wnole or In Pan, In anY form or nr anY m.ana x«e.da ar m.d,.nkr, mdmloe phpr«.Prloy, r«ordke, or br •nr mlormauon awr.e. and rehievr aYarem now Mown or hereener invenrw, wiMOUI wnnen parmiaai« from Baker Huenea Inc. ~guioment Specifications 5.112" X 9-5/8" HOOK Hanger' Mainbore Drift: 7.00" Mainbore Drift, with divartar. 8.25" Lateral Drift, no diwrtar or LEM: 4.D8" Latarel Drift, w/ diwrter, no LEM: 4.80" LaterallMainbora Diwrtar OD: 8.50" 4112" Lateral Entry Module Mainbore Drift: 7.68" Mainbore Drift, wl isdation reeve: 250" LaUral Drill, vM coil diwrtar. 3.00" OD of Diwrter and Sleeve: +l- 3.60" Diwrbr and SNew Length: +l- 19' 'Tbeee d ma a,a ap¢cA c m the PZ rewarFatl puinmem. 0wY Tea. Drawlna No.. woe w.ar sak ovr La.rai cnmPl.nnn-mpowr Data. Novembn a, 1006 a"wn %~ Marc D. Kuck R'ealan Na. ~ ~a.e. ; .-. • GRIGINAL TO I~r\ V a~rr_ D Tubing, Special Drift to +l- 500' MD DB Nipple, set at +/- 500' MD ~. GLM, Camco, 4112" x 1" KBMG 13-3I8" Casing Shoe, /GLM, Camco, 4112" x 1" KBMG 68#, L-80, BTC set ~ // 3589' MD, 2197' TVD CMD Sliding Sleeve, wl DB Nipple Tubing String / 4112" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift Locating Seal A:aemay 4.75" Seal OD 7" X 9-518" ZXP Winer Top Piker Xh Mold Downs Casing Sealbore F 4.75" ID Lateral Entrv Module (LEMI A em I 7" X 9-518" ZXP Liner Top Packer with Hold Downs 7.500" Tieback Ext.ID 6.278" Tool Body ID _~ Casing Sealbore Receptacle 4.75" ID, 5,75" OD 20' Length ~ Odenling Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation - 3.688" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter ~ Seal Bore for Lak2al Isolation -1.688" ID ~\ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 2' Length sv2° x e-sle" ' (PZ Rewark) Seal Borl J.88"ID 4712" 12.6# Lateral Entry Maduk(LEM) Orientirg ProOk D-sand Window at 9100' MD, 3505' ConocoPhi I I i ps West Sak 9-5/8" Injector 1 J-136 Dual Lateral Completion e~ _.~. Planned .... s Baker Oil Tools Late ral Entrv Module (LEMI With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installetl Installed (J.00" Lateral Drift) (2.80" 10 Mainbore Drift) 'GS' Profile far Coil Connector f Running/Retrieving V i (1.00' Len9m) ' Snap lNSnap OUt I j 'i ~ Positive Lacating~ r Back Pressure Valve Oolkt ! (7.60' Length) Lateral IsoWtion ~~ . r• Flux-Thru Swlval Seals ~ I ~ (7.25' Length) / Hydraulic ~ Lateral Diverter ~ I ~ Ramp ~ ~ Disconnect I ~~' IsoktioN Mainbore ~ ' (1.50' Length) Diverter Sleeve i ' ~ / GS Spear ' ~~ , Lateral Isoktion (7.50 Length) seals 6.85 ft Approz DAL' 'Jars may be required in highly deviated 19' Diverter Length 79' Skive Length (7.6#, Hydril 4712" t7.6#, BTC, Stoned Liner Ld0 Slotted Liner Other Jdnt Every Other Jdnt 4112"Bent JOint 3.562" DB Nipple 3. "10 7" X 9-518" ZXP Liner Top Piker T' X 9-5/8" Flex Loek Hanger /Packer AsserNyly at Liner Ranger +/- 9750' MD Casing Sealbore Receptacle 4.75"ID 4112" Guide Shoe 4112" Casing Shoe, 11.6#, L-80 BTCM Set ~ 17101' MD, 3373' TVD Seal Assembly 4.78" Seal OD 3.875"ID '13' Sand Lateral 4112" 11.6#, HYdril 4112" 11.6#, BTC, 521, L-80 Slotted Liner L-80 Slotted Liner ~~ Every Other Jdnt Every Other Jdnt 4112" Eccentric \ ~ Guide Shoe 9-5/8" Casing Shoe, 40.0#, L-80 BTC ~ 9546' MD, 3573' TVDD (85 deg inc) o Baker Hvgnee :pos. rnie ao<vmem mar not be revrodvicea or mehinmed, m wnole or m p.n, m am form or ray any means ekcuonic or mxhaniwl, in<meing photocopying, re<orame, or by any imormmion ewraee ane retrkval system now known or hereafter inventee, without written permission Irom Baker Hughes Inc. ~uioment Specifications 5-112" X 9-518" HOOK Hanger' Mainbore Drift: 7.00" Mainbore Drift, with diverter: 6.25" Lateral Drift, no diverter or LEM: 4.88" Lateral Drft, wl diverter, no LEM: 4.50" Latera#Mainbore Divener OD: 8.50" 4-112" Lateral Entry Module Mainbore Drift: 3.68" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Dritt, wl coil diverter: 3.00" OD of Diverter and Sleeve:+/- 3.60" Diverter and Sleeve Length: +/-19' ~n,e:r mm: aye :pP~~l~._ m In,. 4-112" Casing Shoe, 11.6#, BTCM Set ~ 17408' MD, 3436' TVD 2006 Went sale Dual Lateral Completion -Injector 0.ewn aY: 0.edsbn No.: e Oct 28, 2006 Chuck Bostick 1 • • --F -- SHARON K. ALLSUP-DRAKE 1160 CONOCOPHILLIPS ATO 1530 ~/~/~`7/y-~, 700 G ST. Dare (i ( v`"~-~s-TS51/aai ANCHORAGECAK 99501' [/'/~ PAY TO THE / ~/ I ~C/ ~~ ~ ~ ~ Li t ~k " '-"[ ~~ ~ ~CJI-/, ~~ ORDER OF ~~ !~- ~uM~ JPMorganChase~ j validuPro5000Oouars JPMorgan Chase Bank, N.A. Columbus, OH ~~~4~-- -/~^ _ -- ~--= ---= -nor MEMO ~:044LL551L~:52B747i907927a'~L60 ..._r. , • PT®# 20~ - is Y - ®evelopmen*. ~ Service E~ploratory~ Stratigraphie Test - lion-Conventional ~"ell Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CE-IECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS j APPLIES ' MtiLTI LATERAL ~ The permit is for a new wellbore segment of existing well (If fast two digits in 'permit No. . API No. b0- API number are ~ - between 60-69) ,Production should continue to be reported as a function of the original API number stated above. i PLOT HOLE ~ In accordance with 20 :~aC 2~.00~(f), all records, data and Cogs I acquired for the pilot hole must be clearly differentiated in both ? well name ( PH) and API number t (~0- - -) from records. data and logs '. j ;acquired for well !~ SPACING i~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ?~.0>j. Approval to perforate and produce ,' in}ect is contingent upon issuance of a conservation order approvin4 a spacing ;' exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH 'All do ditch sample sets submitted to the Commission must be in i SAMPLE ' no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. I Please note the following special condition of this permit: i' Non-Conventional production or production testing of coal bed methane is not allowed Yell for (name of well) until after (Com~anv Name) has designed and ~, implemented a water well testing program to provide baseline data on water quality and quantity. SCom anv Name) must contact the i Commission to obtain advance approval of such water wel[ testing nrnaram Rey: l 25/06 C jody`transmiral checklist • • ^^ ~ ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ rn o ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ a °_ j ai ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ °~ N ~ co~~~ O ~ ~ ~ ~ ~ ~ ~ ~ C ' ~ ~ 3, , c O °o. ~ ~ vi ~, N, ~ ~°, ~ ~, c N M: ~ ..I' ~ N' p, f ~ ~ ~ ~ ~ ~ ~ ~ ~, ~ ~ ~ ~ O, ~ ~ ~ N' 3, ~~ ~ 7' 01 O U O W N Q' O v ~ ~ ~ ~ ~ Y, ~ ~ ~ ~ ~ ~ ~ N ~ ~~ ~ ~~ ~ a ~ a~ c Q N, E. a?~ ~, ~~ ~ ~ c c' _ ~ , ~ vi m °~' ~' ° aai' y~ N N N a' O ~' Q O O C E O F•', ~ N~ ~ ~ T N. ~ ~ , N. p. ~ f0 N. : N. ~ ~, ~~, Ul, N N N ~ I ~ N. ~ ~~ ~ f0~ 3~ ~ m. o a ~ ~ ~ ~ ~ ~ ~ ~ ~, ~ ~ ~ ~ ~ -p~ ~~ ~ N ~ $, ~ >~ C7, ~ O. ~ o, pi ~ ~//~ ~ o. , Q O. ~ ~ ~ ~~ °, om L O D ~ N, ~~ ~ C• C~ ~ ~ ~ ~ ~ (6~ ~ ~ ~ ~ p~ ~ p, ~ ~ ~~ ~~ _~ , ~ L, 4 N , ~ f6 . o J ~, ~. m ~ ~ ~ • ~ ~ M; ~ ~ ~ ~ o ~ ~ y, ~ N. ~: ~ ~~ ~ ~ ~ ~ ~ ~, ~ o~ ~, ~ N~ ~, ~ o~ a • ~~ ~j, C, -a O w ~ ~ ~ f6 c ~' N ' ' c' ' ~' O) ~ L c' °~ ~ ~ ~ ~ ~ • ~ ~ ~~ ~ ~ ~ f0 ~ o. c. 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T ~ ~ O, ~ a. , Z ~ O, T N. 0, fa~ ~ ~ ~ ~ ~ N. ~, -~ ~ - ~ -~ O. ~ m O. ~ ~p~ ~ Q, ~ ~ N' L~ N' ~ ~ f6 w ~ i Y ~ v "' QY'~ _ ~Q~ Q~~~ ~~, a: ~g~ ~~, ~ ~z~~, z~w~ ~, ~ ~' ~ ~ ~ ~ . ~ ~ ~ ~ `~ a i ~ ~ O ~ ~ N VA HD N, N, N: W~ f/N N~ N~ H~ W~ N, N, N N, N, N, N, N: VD N, N, N~ N, N N Vh N: N, N, O, Q, W~ N, Q, N~ ~ ~ N, O, O, N~ N~ N, N, N: Q, N, N: f/A N, N, UA UT W~ N, N, N, U)< W~ N, O, N, N~ UN N, N, Q, d Q, U' U. ~ ~ C N. ~ ~ ~ >t 0. ~ ~ 3 ~ 3, o O ~ ~ O Y ~ ~ ~ ~ ~ ~ ~ O, Z, ~, ~~ ~ ~ ~ ~ ~ aai, ~ ~ ~ O, ~ ~, ~ ~ ~ o, ~ ~ ~ O m' N ~ ~ ~ i C' ~ ~ ~ ~ j, G O: N. LL ~ ~ ~ 'C d f6, 7 ~ U, ~ ~ ~ LL-y ~ ~ ~ 'N: N l' , ~ ~ ~ ~ ~ , a ~ N ' U ~ N a ' W w ~ N O ~ ~ . ~ , r,i . D• ~ , ~ ~~ ~ ~ , ~ y, . ~ ~ ~ . ~ ~ . , ~ ~ ~ O 3~ ~~ c, a ' °' O. ' i ' ~ `° ~ p. '00; M, ~' °' °' ~ ~, ' U. N, ,N~ ~ ~ o' a ~ c~ a ' E' O, - °' '~' ~ O: ~ . 0~ ~ Q'~ a' p' '6~ N: ~ ~ o, dl~ ~, ~ U ~ ~ _, L• O ` a~ a `, N' >. O O~ ~, N. ~, ~ ~~ C' ~ L. ots ~ ~ a i C . 7 O ~ c, y ~ O. ~~ ~ Q O Vl to N N N Oi Y Z ' o' c a' a o~ a~' . a a N. N. 4 ~ ~ O. C, a~' m. ~ O: o rn av ~ L, c ~ o, o ~ - =' a E E c c E' ~ ~ o i+>' c' ~ c' in F-` c o atf' ~' ~' c ~ ar a N s a c c , : ~ ~ , o '~ U ~ ~ ci ~ a o 3 ° 0 > m Y .~ ' ~ a ~, w c; ~ ~ o, °, ° c: a v. ° ~ o ' Q, y o o, ~ c ~ ~ ~ o' , ° ~ , ~m . ~ Q. - ~, m, ° ' ~' a o, ° o' o, ° a~ v~ Y Q d, ~, n ~ ~ n m ~ ~, ~, ~ ~ , ~, m. ~ ~ . ~- ~, ~ ° , ~ ~ ~ • ~ o, a 0 ~ o •,_ 3 m. , , c~ ~ m fl, o, ,_ _ a ~ o a E ~ a a~ ~ _~ ~ c ~, ~, Lo M °, v~ ~ o ~, o 3 o, , ~ ~ ~ . o ~ E w o U ~ ° N NI v ` ~ ~ ' N ° ° N ' m 'c o ~ U - o -~ 0 o a. . c, r= a, > o' a~ o, ° ° a' ' ' ' ° ~ a. o: o ' u m ' o ~, ~ o, c' o. ~ ' o' ~ .. o. o. ~: Y a m o' ~ ~' o v E' a~ ~ ; m E o. c, L o u, 7 a a. m .~- ~ c . J a~ °~ , fl a~ d ° o •° a i; O p ~ g 3 °- ~ v; ° U N a o' , ~i ~i - a' ai ~ m' v o' E' rn °' U , U' w. ~ N > °' c' o' . o = ~ L l U, f6. i . ~, O O. O. 01 N '.G VD Q al, UA !!~, O. N , , .L-. r 'C, N, m O'. ~ N (0 f6 N~ 01 ~ N` O N' OS , c. T i' Z. a' ~ C N• ~ O ~~ O, 4 N O ~' N' C, ~~ 4 fl. N, ~' S; N' p, N' N 3, C, .a, pf ~~' c? a+ a• N. c. ~~ ~, ~ . _ 7, O: ~~ ~, p. O~ i ~ O, ~~ ~, a N• 'u. U ~°~ .a -~ a. a. a. o, ~-~ c' m °, n, Q~ ~ a~ z. °~ c, U a~ y' ar a' v o~ .m ~~ L, 3 ~ -a ~ ~; c' o ' ~' a~' ~' c~ m c m' O }' Z a~' ~~ m. °, ~, ~~ ~, ~~ , v o, ;, m, m. m. a?' ~' o` L, c ca o °' c, m. U .~ . ~ m. 3' ° °~ vi a' ~' ~ m. o, U, °~ m m. - ~ ° ~ a - •- ~, ` ~ °' ~ °~ •° ~ : E' o. °~ __ c. v' •~ o. m; N ~ U U ~' ~ ~ c ~ O i c i U U v ~, °. ° , ~, ° ~ a U . Q o ° ~. a~ ~ ci o, o _ > > 3' m. v . m. ~ ' °~ o w i o 3' N' m' a o- J U a E' , - - , - ~ - - - ° ~ ~ - a~, c: - c. H H H c ° ' ~ ° a i ~~ w u Y ~ L a~ , ~ ~; ~i Y ~ d a~ ~ a~ N .a c. °~~ °~ °~ ° v' 4 ~ '~ ~ as 4 a~ a> c m 3. a~' - ~ o ' ~ o, °, , ~, ~', ~, va N m, a N co a. ? ~ ._ o~ a, ~ o. O, O L, c i ° p: ~ ~ ~ ~ ~ ~ a~ ~, a~, a~ c. o, m D U c d~~, ~, , ; ;~n,~;O, O,a; a; U ~;Q,a,z U,~: U:U,U, U,¢, "=,Q: ~~ ~ m:m~v: ~ , ~`~ ~ a,q~n,~n, c.~, ~-. W a "~ _ ~ O ~ N M~~ (p f~ a0 O O N ~ M r V' ~ O r ~ W O _ O N N N N M d' N N t!') O N N n W N N _ O O M M N N M V M M M In O ti O M M M M O M "~.~ U U _ _ ~ ° cfl ( ~ . . O [ w N ap+ N_ ap+ N C U ~ W a+ ~ O ~ C ~ O ~ ~ O r O N N i+ ~J ) y J N i N . ~ ~ ~ ~ ~ C C ° C C7 E ,/ / '`~ J ~k ~ a C i a ~ ~ O L a~ O U ll Ll1 ~ ' ~ a a ~ c_ a w ~ aN a y a s . w c9 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. IJo special effort has been made to chronologically organize this category of information. d ~ • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 06 07:19:34 2007 Reel Header Service name . .......... ..LISTPE Date ......... .......... ..07/03/06 Origin ....... .......... ..STS Reel Name .... .......... ..UNKNOWN Continuation Number.... ..01 Previous Reel Name..... ..UNKNOWN Comments ..... .......... ..STS LIS Writing Library Tape Header Service name . .......... ..LISTPE Date ......... .......... ..07/03/06 Origin ....... .......... ..STS Tape Name .... .......... ..UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments ..... .......... ..STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004725877 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-136 500292333100 ConocoPhillips Alaska Inc. Sperry Drilling Services OS-MAR-07 MWD RUN 3 MWD RUN 4 W-0004725877 W-0004725877 P. ORTH P. ORTH F. HERBERT F. HERBERT 35 11N l0E 1564 2282 .00 126.60 81.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3510.0 2ND STRING 8.500 9.625 9729.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK (AROUND JUNK) ~l~_C ~(~~5~~. . ~ • EXITING THE 1J-136 PB1 WELLBORE AT 8700'MD/3447'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 4 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4 REPRESENT WELL 1J-136 WITH API#: 50-029-23331-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17507'MD/3489'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/06 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 3451.0 17469.0 FET 3490.0 17461.0 RPD 3490.0 17461.0 RPS 3490.0 17461.0 RPM 3490.0 17461.0 RPX 3490.0 17461.0 ROP 3515.5 17507.5 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 3451.0 8700.0 MWD 3 8700.5 9745.0 MWD 4 9745.0 17507.5 S REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3451 17507.5 10479.3 28114 3451 17507.5 RPD MWD OHMM 1.66 2000 44.1409 27915 3490 17461 RPM MWD OHMM 0.43 2000 39.4541 27915 3490 17461 RPS MWD OHMM 1.35 2000 33.8554 27915 3490 17461 RPX MWD OHMM 1.93 1439.19 32.1693 27915 3490 17461 FET MWD HOUR 0.19 104.82 1.25478 27915 3490 17461 GR MWD API 22.83 135.15 68.689 28037 3451 17469 ROP MWD FT/H 0.01 2352.54 200.821 27985 3515.5 17507.5 First Reading For Entire File..........3451 Last Reading For Entire File...........17507.5 File Trailer Service name ............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/03/06 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.......07/03/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER; 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY n ~J VENDOR TOOL CODE START DEPTH GR 3451.0 FET 3490.0 RPX 3490.0 RPS 3490.0 RPM 3490.0 RPD 3490.0 ROP 3515.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-NOV-06 Insite 74.09 Memory 8700.0 3514.0 8700.0 74.0 79.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 12.250 3510.0 l~ Fresh Water Gel 9.10 67.0 9.7 500 4.5 2.400 69.0 1.570 109.4 2.000 69.0 2.500 69.0 Data Format Specification Record Data Record Type .............. ... .0 Data Specification Block Type. ... .0 Logging Direction ............. ... .Down Optical log depth units....... ... .Feet Data Reference Point .......... ... .Undefined Frame Spacing ................. ... .60 .lIN Max frames per record ......... ... .Undefined Absent value .................. ... .-999 Depth Units ................... ... . Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 STOP DEPTH 8700.0 8700.0 8700.0 8700.0 8700.0 8700.0 8700.0 • FET MWD020 HOUR 4 1 68 GR MWD020 API 4 1 68 ROP MWD020 FT/H 4 1 68 Name Service Unit Min Max DEPT FT 3451 8700 RPD MWD020 OHMM 1.66 2000 RPM MWD020 OHMM 0.43 2000 RPS MWD020 OHMM 1.35 53.69 RPX MWD020 OHMM 4.04 30.96 FET MWD020 HOUR 0.23 88.83 GR MWD020 API 22.83 135.15 ROP MWD020 FT/H 0.18 2352.54 First Reading For Entire File..........3451 Last Reading For Entire File...........8700 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header • 20 6 24 7 28 8 First Last Mean Nsam Reading Reading 6075.5 10499 3451 8700 17.5167 10421 3490 8700 13.8138 10421 3490 8700 11.3998 10421 3490 8700 9.6816 10421 3490 8700 1.31231 10421 3490 8700 75.0797 10499 3451 8700 223.956 10370 3515.5 8700 Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8700.5 9684.5 RPS 8700.5 9684.5 GR 8700.5 9692.5 RPX 8700.5 9684.5 RPM 8700.5 9684.5 RPD 8700.5 9684.5 ROP 8700.5 9745.0 LOG HEADER DATA DATE LOGGED: 29-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.09 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9745.0 TOP LOG INTERVAL (FT) 8700.0 BOTTOM LOG INTERVAL (FT) 9745.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 85.9 • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3510.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 52.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPE RATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.500 72.0 MUD AT MAX CIRCULATING T ERMPERATURE : 1.830 1 01.1 MUD FILTRATE AT MT: 2.200 70.0 MUD CAKE AT MT: 2.800 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am 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 8700.5 9745 9222.75 2090 8700.5 9745 RPD MWD030 OHMM 3.41 66.48 16.5137 1969 8700.5 9684.5 RPM MWD030 OHMM 2.77 75.85 15.9446 1969 8700.5 9684.5 RPS MWD030 OHMM 2.3 61.2 13.9231 1969 8700.5 9684.5 RPX MWD030 OHMM 1.93 39.65 11.1227 1969 8700.5 9684.5 FET MWD030 HOUR 0.21 41.09 0.881229 1969 8700.5 9684.5 GR MWD030 API 54.54 131.08 94.5169 1985 8700.5 9692.5 ROP MWD030 FT/H 0.01 791.06 176.023 2090 8700.5 9745 First Reading For Entire File.... ......8700. 5 Last Reading For Entire File..... ......9745 File Trailer • • Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Next File Name......... .STSLIB.003 .1.0.0 .07/03/06 .65535 .LO .STSLIB.004 Physical EOF File Header Service name............ Service Sub Level Name.. Version Number.......... Date of Generation...... Maximum Physical Record. File Type ............... Previous File Name...... .STSLIB.004 .1.0.0 .07/03/06 .65535 .LO .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9693.0 17469.0 RPM 9699.0 17461.0 RPX 9699.0 17461.0 RPD 9699.0 17461.0 FET 9699.0 17461.0 RPS 9699.0 17461.0 ROP 9745.5 17507.5 LOG HEADER DATA DATE LOGGED: 08-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17507.0 TOP LOG INTERVAL (FT) 9745.0 BOTTOM LOG INTERVAL (FT) 17507.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 95.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9729.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil B ase MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S): 60.0 MUD PH: .0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 130 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9693 17507.5 13600.3 15630 9693 17507.5 RPD MWD040 OHMM 4.49 2000 65.5161 15525 9699 17461 RPM MWD040 OHMM 4.64 1743.45 59.6465 15525 9699 17461 RPS MWD040 OHMM 4.42 2000 51.4565 15525 9699 17461 RPX MWD040 OHMM 2.9 1439.19 49.9332 15525 9699 17461 FET MWD040 HOUR 0.19 104.82 1.26354 15525 9699 17461 GR MWD040 API 28.61 104.12 61.0786 15553 9693 17469 ROP MWD040 FT/H 1.9 553.9 188.706 15525 9745.5 17507.5 First Reading For Entire File..........9693 Last Reading For Entire File...........17507.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name........ Date ................ Origin .............. Tape Name........... Continuation Number. Next Tape Name...... Comments............ LISTPE 07/03/06 STS UNKNOWN O1 UNKNOWN STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/03/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File i • • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 06 07:53:17 2007 Reel Header Service name .............LISTPE Date .....................07/03/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/03/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004725877 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-136 PB1 500292333170 ConocoPhillips Alaska Inc. Sperry Drilling Services 06-MAR-07 35 11N l0E 1564 2282 126.60 81.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3510.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE ~~,_ ~Sy ~ ~`r~"r~ • • PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 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 1,2 REPRESENT WELL 1J-136 PB1 WITH API#: 50-029-23331-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8858'MD/3478'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB,001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/06 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 3451.0 8794.0 RPD 3490.0 8786.0 RPM 3490.0 8786.0 RPS 3490.0 8786.0 RPX 3490.0 8786.0 FET 3490.0 8786.0 ROP 3515.5 8858.5 BASELINE CURVE FO R 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 3451.0 8858.5 REMARKS: MERGED MAZN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn • • Optical log depth units...........Feet Data Reference Point .......... ....Undefined Frame Spacing .. ........... .... ....60 .lIN Max frames per record ..... .... ....Undefined Absent value ... ........... .... ....-999 Depth Units .... ........... .... .... Datum Specifica tion Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3451 8858.5 6154.75 10816 3451 8858.5 RPD MWD OHMM 1.66 2000 17.3613 10593 3490 8786 RPM MWD OHMM 0.43 2000 13.7138 10593 3490 8786 RPS MWD OHMM 1.35 53.69 11.3316 10593 3490 8786 RPX MWD OHMM 3.84 30.96 9.63083 10593 3490 8786 FET MWD HOUR 0.23 88.83 1.32346 10593 3490 8786 GR MWD API 22.83 135.15 75.599 10687 3451 8794 ROP MWD FT/H 0.13 2352.54 220.277 10687 3515.5 8858.5 First Reading For Entire File..........3451 Last Reading For Entire File...........8858.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Previous File Name..... ..STSLIB.002 ..1.0.0 ..07/03/06 ..65535 ..LO ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3451.0 8794.0 RPD 3490.0 8786.0 RPM 3490.0 8786.0 RPS 3490.0 8786.0 RPX 3490.0 8786.0 FET 3490.0 8786.0 ROP 3515.5 8858.5 • LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 27-NOV-06 Insite 74.09 Memory 8858.0 3514.0 8858.0 74.0 79.2 TOOL NUMBER 216262 67981 12.250 3510.0 Fresh Water Gel 9.10 67.0 9.7 500 4.5 • 2.400 69.0 1.570 109.4 2.000 69.0 2.500 69.0 Data Format Specification Re cord Data Record Type ......... .... .....0 Data Specification Block Type .....0 Logging Direction ........ .... .....Down Optical log depth units.. .... .....Feet Data Reference Point ..... .... .....Undefined Frame Spacing ............ .... .....60 .lIN Max frames per record .... .... .....Undefined Absent value ............. .... .....-999 Depth Units .............. .... ..... Datum Specification Block sub -type...0 Name Service Order Units Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD20 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3451 8858.5 6154.75 10816 3451 8858.5 RPD MWD020 OHMM 1.66 2000 17.3613 10593 3490 8786 RPM MWD020 OHMM 0.43 2000 13.7138 10593 3490 8786 RPS MWD020 OHMM 1.35 53.69 11.3316 10593 3490 8786 RPX MWD020 OHMM 3.84 30.96 9.63083 10593 3490 8786 FET MWD020 HOUR 0.23 88.83 1.32346 10593 3490 8786 GR MWD020 API 22.83 135.15 75.599 10687 3451 8794 ROP MWD20 FT/H 0.13 2352.54 220.277 10687 3515.5 8858.5 First Reading For Entire File..........3451 Last Reading For Entire File...........8858.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/03/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/03/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File