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207-027
New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 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-105 KUPARUK RIV U WSAK 1J-105 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-105 50-029-23346-00-00 207-027-0 W SPT 3719 2070270 1500 591 593 593 593 148 188 185 182 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-105 Inspection Date: Tubing OA Packer Depth 1275 2000 1960 1955IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509105027 BBL Pumped:0.8 BBL Returned:0.8 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 15:01:40 -08'00' Piy� Z970z-70 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> I Sent: Wednesday, February 19, 2020 10:13 AM I ' j `�1 2e�z+( 2117,0 To: Regg, James B (CED) [[ Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Autry, Sydney; Mowrey, Andrew F; Braun, Michael (Alaska); NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI Well 1J-105 on 2/19/2020 Jim, The low pressure pilot (LPP) on well 11-105 (PTD #207-029, #207-028, #207-027) was returned to service and removed from the "Facility Defeated Safety Device Log' today 2/19/2020, after the well was shut in following diagnostic well work The LPP had been defeated on 2/17/2020 when the well was returned to injection for MBE diagnostic. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 14"!Ut IT- los PI-tZe-7 vz7o Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophiIIips.com> Sent: Monday, February 17, 2020 1:37 PM To: Regg, James B (CED) Supt; Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Braun, Michael (Alaska); Autry, Sydney; NSK Optimization Engr Subject: Defeated LPP/SSV on CPAI Well 1J-105 on 2/17/2020 Jim, The low pressure pilot (LPP) on well 1J-105 (PTD #207-029, #207-028, #207-027) was defeated today, 2/17/2020, after the well was brought back on injection for diagnostic wellwork. The well is currently injecting at 1560 BWPD and the wellhead pressure on a vacuum. The -PP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 K2u. j- -me - Pt 26170Z70 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophill ips.com> Sent: Sunday, February 2, 2020 2:09 PM �11 "13r?o ?Z, To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Autry, Sydney, Mowrey, Andrew F; Braun, Michael (Alaska); NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPA] Well 1J-105 on 2/2/2020 Jim, The low pressure pilot (LPP) on well 1J-105 (PTD #207-029, #207-028, #207-027) was returned to service and removed from the "Facility Defeated Safety Device Log" today 2/2/2020, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 950 BWPD at 195 psi wellhead pressure. The LPP had been defeated on 1/26/2020 when the well was returned to injection for MBE diagnostic. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 Regg, James B (CED) 0'c)7627U From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Sunday, January 26, 2020 6:32 AM 7 4I To: Regg, James B (CED) Cc: CPF1 Ops Supv; CPF1&2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI Well 1J-105 on 1/25/2020 Jim, The low pressure pilot (1 -PP) on well 1J-105 (PTD #207-029, #207-028, #207-027) was returned to service and removed from the "Facility Defeated Safety Device Log" last night, 1/25/2020, after the well was shut in following diagnostic well work. The LPP had been defeated on 12/12/2019 when wellhead pressure went on a vacuum shortly after returning the well to service. 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 Salk Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 KN /J -(us (?T -L z0 7&Z-7VRegg, James B (CED) From: NSK West Salk Prod Engr <nl638@conocophillips.com> I/)Z., Sent: Sunday, January 26, 2020 1:58 PM 1 �yv To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Autry, Sydney; Mowrey, Andrew F; Braun, Michael (Alaska) Subject: Defeated LPP/SSV on CPAI Well 1J-105 on 1/26/2020 Jim, The low pressure pilot (LPP) on well 1J-105 (PTD #207-029, #207-028, #207-027) was defeated today, 1/26/2020, after was returned to injection to re -attempt diagnostic wellwork. The well is currently injecting at 992 BWPD and the wellhead pressure is 4 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 Regg, James B (CED) r 71S Zc' 702,7 0 From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Thursday, December 12, 2019 10:02 AM `( To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; NSK Optimization Engr; CPF1 Ops Supv, CPF1 &2 Ops Supt; Autry, Sydney, Braun, Michael (Alaska); Mowrey, Andrew F Subject: Defeated LPP/SSV on CPAI Well 11-105 on 12/12/2019 Jim, The low pressure pilot (LPP) on well 1J-105 (PTD #207-029, #207-028, #207-027) was defeated today, 12/12/2019, after the wellhead pressure fell below the LPP setpoint while evaluating the success of recent wellwork performed. The well is currently injecting at 649 BWPD and the wellhead pressure on a vacuum. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 4497 Well To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 207027 31463 CASED HOLE Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Profile 2) Signed Print Name: READ Cased Hole, Inc. RECEIVED Attn: Diane Williams NOV 19 2019 4141 B Street Suite 308 Anchorage, AK 99503 AOGCC Diane.Williams(a)readcasedhole com 29 -Oct -19 1J-105 CD 50-029-23346-00 Date : I Z zl� � l READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL: READ-ANCHORAGEr(DREADCASEDHOLECOM WEBSITE: WWW,READCASEDHOLE.COM https'Ureadcesedhole-my.shuepoint.com/pmonal/diene williams_resdrasedhole wm/Doc ..wD Driv&AckivcvManerTemplatgilesQ 11.1e,UisNbutioMGns amitta Sheed/ConocOPM]Iips_Transmicdocx Regg, James B (CED) zc�OZ2C3 From: NSK West Sak Prod Engr <n1638@conocophi IIips.com> r— Sent: Saturday, November 16, 2019 2:45 PM To: Regg, James B (CED) T� 111 Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK West Salk Prod Engr Subject: LPP/SSV Returned to Service on CPAI well 11-105 on 11/9/2019 Jim, The low pressure pilot (LPP) on well V-105 (PTD #207-029, #207-028, #207-027) was returned to service and removed from the "Facility Defeated Safety Device Log" on 11/9/2019, after the well was shut in following the MBE diagnostic well work. The LPP had been defeated on 10/23/2019 after the well was returned to service to perform diagnostic well work. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 WCk IJ -165 Regg, James B (CED) P7b 7,0 11-L7o From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, October 23, 2019 12:31 PM To: Regg, James B (CED) i Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; CPF1 Prod Engr; NSK Optimization Engr Subject: Defeated LPP/SSV on CPAI well 1J-105 on 10/23/2019 Jim, The low pressure pilot (LPP) on well 11-105 (PTD #207-029, #207-028, #207-027) was defeated today, 10/23/2019, after the well was returned to service today to perform diagnostic wellwork. The well is currently injecting 640 BWPD and wellhead pressure is on vacuum. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Best Regards, Danila Shutemov / Toon Changklungdee / Marina Krysinskil WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 410 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg G 5'I DztlATE: Monday,May 14,2018 P.I.Supervisor t t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1J-105 FROM: Lou Laubenstein KUPARUK RIV U WSAK 1J-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.113/2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-105 API Well Number 50-029-23346-00-00 Inspector Name: Lou Laubenstein Permit Number: 207-027-0 Inspection Date: 5/9/2018 Insp Num: mitLOL180510143806 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1J-105 Type In,l W- TVD 3719 Tubing 582 _ 585 - 584 - 582 • PTD ( 2070270 Type Test SPT Test psi 1500 IA j 1150 2000 • 1960 • 1950 - BBL Pumped: T 1 - BBL Returned: I OA 149 - 240 - 231 • 224 - Interval 4YRTST P/F l P ,/ Notes: SCANNED JUN 0 4201`d Monday,May 14,2018 Page 1 of 1 ri • or v T 9 N s O0 n C7 ti W N O Ls Ar v °r© Qi s oI� 2 �p @ p co o • r- ro +, O +0.+ N O '. 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H C Q ro .� t11 N O Cn 13 Q it a` d Q • • VA"( 1fps prb a o z:10 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> / Sent: Wednesday, June 28, 2017 4:47 AM 'r17 To: Regg, James B (DOA) I 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-105 - 06/27/2017 Jim, -I The low pressure pilot(LPP) on well 1J-105 (PTD#207-027, 207-028, 207-029)was returned to service and removed from the"Facility Defeated Safety Device Log" on 06/27/2017. The well is currently injecting at approximately 1245 BWPD with a wellhead injection pressure of 170 psi. -� The LPP had been defeated on 06/27/2017, when the wellhead injection pressure fell below 150 psig. This notification is in accordance with "Administrative Approval No. CO 406B.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: n1638conocophillips.com SCANNED ' 2Q1 1 • ►<2u c j Iz)( Pit Regg, James B (DOA) 2oaazro From: NSK West Sak Prod Engr <n16380conocophillips.com> Sent: Sunday, June 18, 2017 7:12 PM IC/ /1/( 7 To: Regg, James B (DOA) l Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt; Effiong, Michael; Stanley, Scott M Subject: LPP/SSV Returned to Service on CPAI well 1J-105 - 06/18/2017 Jim, The low pressure pilot(LPP) on well 1J-105 (PTD#207-027, 207-028, 207-029)was returned to service and removed from the"Facility Defeated Safety Device Log" on 06/18/2017. The well is currently injecting at approximately 1120 BWPD with a wellhead injection pressure of 185 psi. The LPP had been defeated on 06/06/2017. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Pager: 1 907 659-7000 pg. #497 Email: n1638 aC�conocophillips.com SCANNED ' EP 1 } 2017. q- 1a-105 • • Pr6 ze 7 0 2-7 o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, June 7, 2017 5:13 PM `eO 6( t 1( 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; Sullivan, Michael; Krysinski, Marina L; Targac, Gary; Effiong, Michael; Stanley, Scott M Subject: Defeated LPP/SSV on CPAI well 1J-105 on 06/06/2017 Jim, The low pressure pilot(LPP) on well 1J-105 (PTD#207-02 , 207-028, 207-029)was defeated on 06/06/2017, after the well head injection pressure fell below 150 psig. e L and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 560 BWPD at a wellhead injection pressure of 155 psig. 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. Thank you. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 Email: n1638conocophillips.com SCAN JUL 1 720 1 Katt I s- Ds- f2 7,e9 7OV7 o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> i Sent: Tuesday, May 30, 2017 11:01 AM '1 e 51301 r 3 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt; Effiong, Michael; Stanley, Scott M Subject: LPP/SSV Returned to Service on CPAI well 1J-105 - 05.30.2017 Jim, The low pressure pilot(LPP) on well 1J-105 (PTD#207-027, 207-028, 207-029)was returned to service and removed from the"Facility Defeated Safety Device Log" on 05/30/2017. The well is currently injecting at approximately 556 BWPD with a wellhead injection pressure of 262 psi. The LPP had been defeated on 05/09/2017. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Pager: 1 907 659-7000 pg. #497 Email: n1638 anconocophillips.com SCANNED .lly/ 4201? 1 STATE OF ALASKA taKA OIL AND GAS CONSERVATION COMMI V REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ PluLerforations Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ ❑ Perforate Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ PerforD New Pool Repair Well ❑ Re-enter Susp Well❑ Other: MBE GEL JOB ❑ 2.Operator , 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 207-027 3.Address: Stratigraphic❑ Service E 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23346-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,ADL 25662 KRU 1J-105 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 11,735 feet Plugs measured None feet true vertical 3,823 feet Junk measured None feet Effective Depth measured 11,725 feet Packer measured 7288, 7465, 7820 feet true vertical 3,823 feet true vertical 3636,3661, 3719 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 " 108'MD 108 SURFACE 3,356 feet 10 3/4" 3,387'MD 2254 PRODUCTION 8,811 feet 8 " 8,838'MD 3820 SLOTTED LINER 3,905 feet 4 1/2" 11,725'MD 3823 RECEIVED Perforation Depth Measured depth 8863-9769, 10068-11682 feet MAY 1 9 2017 True Vertical depth 3821-3813, 3810-3822 feet AO X Tubing(size,grade,measured and true vertical depth) 4.5" L-80 7,324'MD C 3,642'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 7,288' MD 3,636'TVD PACKER=ZXP Liter Top Packer 7,465'MD 3,661'TVD PACKER=HRD ZXP Liter Top Packer 7,820'MD 3,719'ND SSSV: NIPPLE 498'MD 498'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED „JUN 1 32017 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: - - 401 - 33 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ ServidI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 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: 317-081 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@conocophillips.com Authorized Title: Sr.Wells Engineer $r'7/i Contact Phone: (907)265-6471 Authorized Signature: - � Date: 7 94 _ - Form 10-404 Revised 4/2017 V 4 f 7-!j Submit Original Only 41eG17 71 RBDMSSAY192017 • • IJ- 105 DTTMS.JOBTYP SUMMARYOPS 4/26/17 NRWO PERFORM PASSING MIT-IA, PULL TYPE 1 ISOLATION SLEEVE AT 7707' RKB, SET DB-6 PLUG AT 7809' RKB, SET PRONG IN DB-6 PLUG AT 7809' RKB, JOB IN PROGRESS. 4/27/17 NRWO SET TYPE 1 DIVERTER IN B LEM AT 7707' RKB, SET NEW STYLE ISOLATION SLEEVE (2.75" ID)ACROSS D LEM AT 7348' RKB, FLAG PIPE FOR DEPTH CORRELATION, JOB IN PROGRESS. 4/28/17 NRWO RIH TO FLAG AND CORRECT DEPTH TO RKB, CONTINUE TO RIH TO FIRE 2.0" OD POWERFLOW PERF GUNS (6 SPF/60 DEG PHASE), TOP SHOT AT 9745' RKB, BOTTOM SHOT AT 9750' RKB, READY FOR RPPG PUMPING, JOB IN PROGRESS. 4/30/17 NRWO RUN#1, UNABLE TO PASS B SAND DIVERTER AT 7707' RKB, RUN#2 TAG AGAIN AT 7707' RKB, PUMP 3308 LBS OF REFORMED PARTICLE POLYMER GEL (RPPG)AT AN AVERAGE .75 PPG CONCENTRATION WITH 70 DEGREE SEAWATER, PUMP 275 LBS POLYSWELL GEL AT .20 PPG, FLUSH WITH 15 BBLS SEAWATER AND PUMP DIESEL DISPLACEMENT WHILE POOH, WAIT 48 HOURS BEFORE FCO, JOB IN PROGRESS. 5/1/17 PUMPING PUMPED 43 BBLS DSL DOWN TBG FOR FREEZE PROTECT( JOB TRACKING COMPLETE) ONLY PUMPED 4 BBLS NEAT METH DOWN F/L FOR FREEZE PROTECT(JOB COMPLETE) 5/3/17 NRWO RIH WITH DJN, CLEAN OUT DOWN TO 10913' CTMD GETTING BACK 97% RETURNS, GOT BACK LESS THEN A BBL OF RPPG AND SLIGHT CONCENTRATIONS OF POLLY SWELL. TURN OVER TO DSO (JOB COMPLETE) a KUP I 1J-105 conotoP°U Ilps s Well Attribut Max Angle. TD Alaska.Irks. Wellbore APUUWI Field Name Wellbore Status ncl(-) MD(ftKB) Act Btm(ftKB) {g *glips,.. 500292334600 WEST SAK INJ 92.96 9,846.46 11,735.0 ... Comment H2S(ppm) Date Annotation End DateKB-Grd(tt) -Rig Release Date 1J-105,5/17/20178:02:06 AM SSSV:NIPPLE Last WO: I 32.29 4/29/2007 Veda acbamanc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL A SAND DB PLUG W/ pproven 11/20/2016 HANGER;23.0.---t, ( PRONG,DIVERTER,ISO SLEEVE,SET ISO Casing Strings - r- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ' "'CONDUCTOR 20 19.124_ 30.0 108.0 108.0 94.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread SURFACE 10 3/4 9.950 30.5 3,386.8 2,254 4 45 50 L 80 BTC _ets-.CONDUCTOR;30.0.708.0- INKCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread NIPPLE;498.3i WINDOW D 8 7.000_ 7,348.0 7,363.0 3,647.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade -Top Thread GAS LIFT;2,267.8 -� WINDOW B 8 7.000 7,707.0 7,722.0 3,703.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade 'Top Thread PRODUCTION 7 5/8 6.875 27.4 8,838.4 3,820.3 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;30.5-3,366.8-. L D-Sand Liner LEM 4 1/2 3.958 7,288.4 7,494.8 3,666.2 12.60 L-80 IBTM Liner Details Nominal ID GAS LIFT;6,393.7 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,288.4 3,635.9 79.45'PACKER L2 D-SAND LEM ZXP 5-1/2"x 7-5/8" Liner Top 4.940 SLEEVE-C;6,691.311111 Packer TOP 7,307.5 3,639.2 80.46 CSR L2 D-SAND LEM Casing SBR 109-47 C 6.26"OD x 4.750 LOCATOR;7,295.6 4.75"ID SEAL ASSY;7,296.6 - 7,327.1 3,642.3 81.50 BUSHING L2 D-SAND LEM Reducing XO Bushing 5-1/2"Hydril 3.930 563 x 4-1/2"IBT 11. 7,332.3 3,643.0 81.77 HANGER L2 D-SAND LEM Above Hook Hanger 3.960 i1 !f`{ 7,343.3 3,644.5 82.35 HANGER L2 D-SAND LEM Inside Hook Hanger 3.688 WINDOW D;7,318.0-7,363.0 t�+ Wr:pcbck D;7,347.0 I i it 7,491.5 3,665.6 80.39 SEAL ASSY L2 D-SAND LEM Baker Seal Assembly 4-1/2"STL 3.860 Box up Casing Description OD(in) ID lie) Top(ftKB) Set Depth((tKB) Set Depth(ND)...WtlLen(I...Grade Top Threatl D-Sand Liner HH I 4 1/21 3.476 7,343.31 7,611.81 3,686.71 11.601 L-80 BTC Liner Details _. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) DSand Liner LEM,7,286.4 7,494.8 . 7,343.3 3,644.5 82.35 HANGER L2 D-SAND HOOK ASSY Baker Model B-1 Hook 5.600 Hanger 7 5/8"x 4 1/2"(Inside csg) a, 7,360.0' 3,646.7 82.39 HANGER 'L2 D-SAND HOOK ASSY Baker Model B-1 Hook 4.000 Hanger 7 5/8"x 4 1/2"(Outside csg) 7,505.3' 3,668.0 79.94 ECP 1_2 D-SAND HOOK ASSY Baker Payzone External 3.960 D-Sand Una HI-I;7,343.3- Casing Packer 7,611.8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread i3 dt B-Sand Liner LEM I 41/21 3.9581 7,464.81 7,862.51 3,725.41 12.60)L-80 IBT ISO SLEEVE;7,7070, Liner Details Whipstock B;7,707.0 WINDOW B,7,707.0-7,722.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,464.8 3,661.4 81.28 PACKER L1 B-SAND LEM ZXP 5-1/2"x 7-5/8" Liner Top 4.767 Packer TOP 7,483.8 3,664.3 80.65 CSR L1 B-SAND LEM 109-47 Casing SBR 6.26"OD x - 4.750 4.75 7,503.5 3,667.6 80.00 BUSHING L1 B-SAND LEM XO Bushing 5-1/2"Hydril 563 x 4- 3.958 II?:'.'' _ 1/2"IBT •'' 7,696.5 3,699.3 81.21 HANGER L1 B-SAND LEM LEM Above Hook Hanger 3.688 I' ,: " 7,703.3 3,700.4 81.18 HANGER L1 B-SAND LEM LEM Inside Hook Hanger 3.688 0-Sand Liner LEM;7,464.8- _ 7,8625 Alli&M.. 7,809.3' 3,717.1 80.72 NIPPLE L1 B-SAND LEM Camco"DB-6"Nipple,I.D.3.562", 3.562 •Ialil IBT 8-Sand Liner HH;7.703.3- 7,859.2' 3,724.9 81.40 SEAL ASSY L1 B-SAND LEM Baker Seal Assembly 4-1/2"STL 3.860 7,893.8 Box up PRODUCTION;27.4-2838.4 Casing Description 100(in) �ID(in( I Top(ftKB) ISet Depth(ftKB) ISet Depth(TVD)...I WtlLen(I...I Grade Top Thread B-Sand Liner HH 4 1/2 3.476 7,7033 7,893.8 3,7300 11.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,703.3 3,700.4 81.18 HANGER L1 B-SAND Baker Model B-1 Hook Hanger 7 5/8"x 4 5.640 1/2"(Inside) SLOTS;8,853.0-9,765.0 7,720.0 3,703.0 81.08 HANGER L1 B-SAND Baker Model B-1 Hook Hanger 7 5/8"x 4 5.640 1/2"(Outside) Casing Description I OD(in) IID(in) Top(ftKB) I Set Depth(ftKB) 'Set Depth(ND)...'WtJLen(l...1Grade Top Thread A-Sand Slotted Liner 41/2 3.476 7,8200 11,725.0 3,822.7 11.60 L-80 BTC w/TR Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 7,820.0 3,718.8 80.68 PACKER A-SAND 5.5"x 7.63"Baker"HRD"ZXP Liner Top Pkr 5.500 7,839.0 3,721.8 81.03 SEAL NIPPLE 'A-SAND"RS"Packoff Seal Nipple,6.07"OD/4.87" 4.870 ID 7,841.8 3,722.3 81.08 HANGER A-SAND 5.5"X 7.63""Flex-Lock"Liner Hgr,6.59" 4.850 OD/4.85"ID 7,851.6 3,723.81 81.26 ISBE IA-SAND 190-47 Seal Bore Ext,6.29"OD/4.75"ID I 4.750 Tubing Strings 1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.992 23.0 7,323.9 3,641.8 12.60 L-80 IBT SLATS;10,088.0-11,682.0 • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 23.0 23.0 0.00 HANGER TUBING HANGER w/PUP 3.992 498.3 497.7 7.11 NIPPLE CAMCO DB NIPPLE 3.875 6,691.3 3,494.6 69.09 SLEEVE-C CMU SLIDING SLEEVE (CLOSED ON 6/29/2007) 3.812 7,295.5 3,637.2 79.82 LOCATOR LOCATOR 3.880 7,296.6 3,637.3 79.88 SEAL ASSY GBH-22 LOCATING SEAL ASSEMBLY 3.880 A-Sand Slotted Una;7,820.0- 11,725.0-\ ,820.0- 11,725.01 KUP I 1J-105 ConotoPhillips Alaska.(no. ConeopPhatips IT aa.< ••• 1J-105,5/17/20178:02:06 AM Verticall achromatic(actual) HANGER;23.0 acm:„•_m. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) v. Top(ND) Top Incl Top(ftKB) (ftKB) (°) Dee Corn Run Date ID(En) III' 7,347.0 3,645.0 82.54 Whipstock D D-SAND WHIPSTOCK 4/22/2007 7,707.0 3,701.0 81.16 ISO SLEEVE TYPE 1 ISO SLEEVE IN B-SAND '11/8/2016 3.750 -",-^CONDUCTOR,30.0-108.0' NIPPLE;499.3 IM 7,707.0 3,701.0 81.16 Whipstock B B-SAND WHIPSTOCK 4/9/2007 GAS LIFT,2,267.8 '�II Perforations&Slots Shot Top(ND) Btm(ND) (ssh ts/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com SURFACE,30.5-3,386.8 4 i8,863.0 9,769.0 3,821.1 3,813.0 WS A2,1J- 4/26/2007 32.0 SLOTS Alternating solid/slotted 105 pipe 2.5"long x.125" wide GAS LIFT,6,393.7 , l10,068.0 11,682.0 3,810.0 3,822.4 WS A2,1J- 4/26/2007 32.0 SLOTS Alternating solid/slotted SLEEVE-C,6.691.3 11111 wide r' Mandrel Inserts 105 pipe 2.5"long x.125' 11E LOCATOR,7,295.5 St SEAL ASSY;7,296.6 ..F i ai on N Top(TVD) Valve Latch Port Sire TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (En) (psi) Run Date Corn 1 i 1 2,267.8 1,853.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/28/2007 Whipstock D;7,3470 1`11 �� 2 6,393.7 3,387.0 CAMCO KBMG 1 GAS LIFT DMY BEK-5 0.000 0.0 4/28/2007 • WINDOW D,7,348.0-7,363.0 1 �1. Notes:General&Safety I Ill/ End Date Annotation 4/29/2007 NOTE: MULTI-LAT WELL-1J-105(A-SAND),1J-105L1(B-SAND),1J-105L2(D-SAND) 3/2/2011 NOTE:View Schematic w/Alaska Schematic9.0 It_ 9/24/2012 NOTE:PROFILE MODIFICATION-PUMPED 2090 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 D-Sand Liner LEM,7,288.4- 8/10/2013 NOTE: PROFILE MODIFICATION-PUMPED 3100 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 7,494.8 ! IID-Sand Liner HH,7,343.3- 7,611.8 ISO SLEEVE;7,707.0.E Whipstock B;7,707.0 WINDOW B,7,70713-7,722 0 Aj l �F i i� . .1 tallaE B-Sand liner LEM;7,464.8- .Q 7,862.5 Illt B-Sand Liner HH,7,703.3- 7,893.8 I PRODUCTION,27.4-8,838.4 SLOTS,8,863.0-9,769 0 SLOTS,10,068.0-11,682.0 A-Sand Slotted Liner,7,820 0- 117250L—. pit z.,0701.-10 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> ,I j Sent: Tuesday, May 9, 2017 3:33 PM 1e7f(t 1 t l ( 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; Sullivan, Michael; Krysinski, Marina L; Targac, Gary; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1J-105 on 05/09/2017 Jim, The low pressure pilot (LPP) on well 1J-105 (PTD# 2070270, 2070280, 2070290) was defeated today, 5/09/2017, after the well was put on water injection service following an extended shut-in period. The well is currently injecting at a wellhead injection pressure of-3 psi and rate of 490 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. 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 • yoF T� \ ly7,-4",tA THE STATE Alaska Oil and Gas ti ,:-s OfA LAsKAL Conservation Commission _ 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r,-Try o, Main: 907.279.1433 • A ;SA Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer AP 2 020 ConocoPhillips Alaska, Inc. SCWE� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-105 Permit to Drill Number: 207-027 Sundry Number: 317-081 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 3.1.05.080, 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, '1C2 Daniel T. Seamount, Jr. Commissioner r DATED this6`7 day of February, 2017. RBDMS FEB 2 7 2017 RE • STATE OF ALASKA • FEB 1 511/2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY.APPROVALS A GCC 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations E Fracture Stimulate 1- Repair Well 1– Operations Shutdown E Suspend n Perforate E Other Stimulate E Pull Tubing E Change Approved Program E Plug for Redrill n Perforate New Pool r Re-enter Susp Well r Alter Casing fl Other: MBE GEL JOB P. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory E Development mm 207-027 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic { Service ` 50-029-23346-00 , 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 r No I KRU 1 J-105 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,ADL 25662 = Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,735' . 3,823' • 11725 , , 3823 1500 NONE NONE Casing Length Size MD ND Burst Collapse Conductor 78' 20" 108' 108' Surface 3,356' 10 3/4 3,387' 2,254' Production 8,811' 7 5/8 8,838' 3,820' Liner 3,905' 4 1/2 11,725' 3,823' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8863-9769, 10068-11682 3821-3813,3810-3822 4.500" L-80 7,324' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=ZXP LINER TOP PACKER ' MD=7289,TVD=3638 PACKER=ZXP LINER TOP PACKER ' MD=7465,TVD=3658 PACKER=BAKER HRD ZXP LINER TOP PACKER , MD=7820.TVD=3719 SSSV: =NONE N/A 12.Attachments: Proposal Summary 2 Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory fl Stratigraphic r" Development I' Service P 14.Estimated Date for 3/14/2017 15.Well Status after proposed work: Commencing Operations: OIL E WINJ WDSPL r Suspended E 16.Verbal Approval: Date: GAS r WAG E GSTOR E SPLUG E Commission Representative: GINJ E Op Shutdown E Abandoned E 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.Peirce@conocophillips.com Printed Name John Peirce Title Sr.Wells Engineer t . ,a. 2/14-/i 7 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 ❑ Mechanical Integrity Test ❑ Location Clearance ❑ F- I-12_1,111 Other: Post Initial Injection MIT Req'd? Yes ❑ No LN RBDMS t` FEB 2 J 2017 Spacing Exception Required? Yes ❑ No Q/ Subsequent Form Required: /t) — 4 D 4 i y 2 APPROVED BY Approved by: • / COMMISSIONER THE COMMISSION Date: 2/25 /t /�/ ` '���'''��j Subnn,Furm and Fo 1 -403 R vis d 1 i z V 44IAi IS valid12 thS from the date of approval. Attachments in Duplicate q"S" f�s t Irt' %/7 KUP I 1J-105 Con©4coPhwllips 4 `� Well Attribute Max Angle D TD 3Il.k`E Ir4 )Wellbore APUUWI Field Name Wellbore Status rid(°) MD(ftKB) Act Btm(ftKB) tarwaFhink s 500292334600 WEST SAK INJ 92.96 9,846.46 11,735.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1J-105,2/13/2017 101 7:32 AM SSSV:NIPPLE Last WO: 32.29 4/29/2007 Verhalsohema0c(aortal) "Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL A SAND DB PLUG W/ pproven 11/20/2016 HANGER;23.0---1.. KJ f 1 PRONG,DIVERTER,ISO SLEEVE,SET ISO Casing Strings o Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 9400 H-40 WELDED Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9950 30.5 3,386.8 2,2544 45.50 L-80 BTC -A-A.CONDUCTOR;30.0-105.0- I I "° Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ini NIPPLE;498.3 M`= WINDOW D 8 7.000 7,348.0 7,363.0 3,647.1 casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread GAS LIFT;2,267.8 WINDOW B 8 7.000 7,707.0 7,722.0 3,703.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread PRODUCTION 7 5/8 6.875 27.4 8,838.4 3,820.3 • 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE;30.5.3,386,8-, 1 1 D-Sand Liner LEM 4 1/2 3.958 7,288.4 7,494.8 3,666.2 12.60 L-80 IBTM Liner Details iism GAS LIFT;8,393.7 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) law 7,288.4 3,635.9 79.45 PACKER L2 D-SAND LEM ZXP 5-1/2"x 7-5/8" Liner Top 4.940 SLEEVE-C;6,691.3 Packer TOPkill ° 7,307.5 3,6392 80.46 CSR L2 D-SAND LEM Casing SBR 109-47 C 6.26"OD x 4.750 LOCATOR;7,295.5 4.75'ID SEAL ASSY;7,2866 7,327.1 3,6423 81.50 BUSHING 12 D-SAND LEM Reducing XO Bushing 5-1/2"Hydril 3.930 - 563 x 4-1/2"IBT (r �7 ,332.3 3,643.0 81.77 HANGER L2 D-SAND LEM Above Hook Hanger 3.960 7,343.3 3,644.5 82.35 HANGER L2 D-SAND LEM Inside Hook Hanger 3.688 Whipstock D;7,347.0 _€€€1� 7,491.5 3,665.6 80.39 SEAL ASSY L2 D-SAND LEM Baker Seal Assembly 4-1/2"STL 3.860 WINDOW D;7,348.0-7,363.0 E i- Box up Casing Description I OD(in) IID(in) ITop(ftKB) I Set Depth(ftKB) Set Depth(ND)...I WULen(I...I Grade Top Thread D-Sand Liner HH 4 1/2 3.476 7,343 3 7,611 8 3,686.7 11.60 L-80 BTC Liner Details gg Nominal ID .�..T Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) D-Sand Liner LEM;7,288.4- 7,49411 li rk�-ill 7,343.3 3,644.5 82.35 HANGER L2 D-SAND HOOK ASSY Baker Model B-1 Hook 5.600 Hanger 7 5/8"x 4 1/2"(Inside csg) e. 7,360.0 3,646.7 82.39 HANGER L2 D-SAND HOOK ASSY Baker Model B-1 Hook 4.000 Hanger 7 5/8"x 4 1/2"(Outside csg) 7,505.3 3,668.0 79.94 ECP L2 D-SAND HOOK ASSY Baker Payzone External 3.960 0-Send Liner HH;7,343.3- Casing Packer 7,611.8 Casing Description I OD(in) IID(In) I Top(ftKB) I Set Depth(ftKB) I Set Depth(ND)...IWULen 0...1Grade Top Thread �ti of B-Sand Liner LEM 4 1/2 3.958 7,464 8 7,862.5 3,725.4 1260 L-80 IBT ISO SLEEVE;7707.OsLiner Details Whipstock B;7,707.0 , WINDOW B;7,707.0-7,722.0 /i. Nominal ID j. Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) /,464.8 3,661.4' 81.28 PACKER L1 B-SAND LEM ZXP 5-1/2"x 7-5/8" Liner Top 4.767 Packer TOP 7,483.8 3,664.3' 80.65 CSR L1 B-SAND LEM 109-47 Casing SBR 6.26"OD x 4.750 4.75 7,503.5 3,667.6 80.00 BUSHING L1 B-SAND LEM XO Bushing 5-1/2"Hydril 563 x 4- 3.958 1/2"IBT F • 7,696.5 3,699.3 81.21 HANGER L1 B-SAND LEM LEM Above Hook Hanger 3.688 I,�. 7,703.3 3,700.4 81.18 HANGER L1 B-SAND LEM LEM Inside Hook Hanger 3.688 B-Sand Liner LEM;7,464.8- 7,862.5 • ': 7,809.3' 3,717.1 80.72 NIPPLE L1 B-SAND LEM Camco"DB-6"Nipple,I.D.3.562", 3.562 S' IBT e-sand Liner HH;7703.3- 7,859.2' 3,724.9 81.40 SEAL ASSY L1 B-SAND LEM Baker Seal Assembly 4-1/2"STL 3.860 7,893'5 I Box up PRODUCTION;27.4-8,838.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B-Sand Liner HH 41/2 3.476 7,703.3 7,893.8 3.730.0 11.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl B) Item Des Com (in) • 7,703.3 3,700.4 81.18 HANGER L1 B-SAND Baker Model B-1 Hook Hanger 7 5/8"x 4 5.640 1/2"(Inside) SLOTS;6.883.09,789.0 7,720.0 3,703.0 81.08 HANGER L1 B-SAND Baker Model B-1 Hook Hanger 7 5/8"x 4 5.640 1/2"(Outside) Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I A-Sand Slotted Liner 4 1/2 3.476 7,820.0 11,725.0 3,822.7 11.60 L-80 BTC wl TR Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl Cl Item Des Com (in) 7,820.0 3,718.8 80.68 PACKER A-SAND 5.5x 7.63"Baker"HRD"ZXP Liner Top Pkr 5.500 7,839.0 3,721.8 81.03 SEAL NIPPLE A-SAND"RS"Packoff Seal Nipple,6.07"OD/4.87" 4.870 ID 7,841.8 3,722.3 81.08 HANGER A-SAND 5.5"X 7.63""Flex-Lock"Liner Hgr,6.59" 4.850 OD/4.85'ID SLOTS;10,088.0-11,882.0 7,851.6 3,723.8 81.26 SBE A-SAND 190-47 Seal Bore Ext,629"OD/4.75'ID 4.750 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB( Set Depth(ft...Set Depth(TVD)I...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.992 23.0 7,323.9 23.0 3.641.8 12.60 L-80 IBT Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 23.0 0.00 HANGER TUBING HANGER w/PUP 3.992 498.3 497.7 7.11 NIPPLE CAMCO DB NIPPLE 3.875 6,691.3 3,494.6 69.09 SLEEVE-C CMU SLIDING SLEEVE(CLOSED ON 6/29/2007) 3.812 7,295.5 3,637.2 79.82 LOCATOR LOCATOR 3.880 7,296.6 3,637.3 79.88 SEAL ASSY GBH-22 LOCATING SEAL ASSEMBLY 3.880 1 1 A-Sand Slotted Liner;7,020.0- 11,725.0N 11 * KUP 1111 1J-105 Con©caPhiHips Alaska.(no:, • ••• 1J-105,2/13/201710:17:33 AM Veronal schematic(echo) HANGER,23.0 ':•""...- Er 11 7 �.. I 11 r'1141 - Top Com Run Date ID(in) �l 1 1 • • • • 11 7,707.0 3,701.0 • • • 16 3 750 M CONDUCTOR;30.6108.0- M- NIPPLE;498.3 7,707.0 1 1 •WHIPSTOCK 11 GAS LIFT;2,267.8 � . Perforations&Slots mos Shot SURFACE;305-3,3843.8-. •,8,863.0 9,769.0 3,821.1 3,813.0 WS A2,1J- 4/26/2007 32.0 SLOTS Alternating solid/slotted 105 pipe 2.5"long x.125" MAE wide GAS LIFT;6,393.7PM __ 10,068.0 11,682.0 3,810.0 3,822.4 WS A2,1J- 4/26/2007 32.0 SLOTS Alternating solid/slotted 105 pipe 2.5"long x.125" SLEEVE-C;6,691.3 wide Mandrel Inserts LOCATOR;7,295.5 SEAL ASSY;7,296.8 St ati 1,, ,., 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 ir' 1 2,267.8 1,853.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/28/2007 Whipstock D;7,317.0 2 6,393.7 3,387.0 CAMCO KBMG 1 GAS LIFT DMY BEK-5 0.000 0.0 4/28/2007 WINDOW D;7,348.0-7,383.0 it• Notes:General&Safety E I End Date Annotation 4/29/2007 NOTE: MULTI-LAT WELL-1J-105(A-SAND),1J-105L1(B-SAND),1J-105L2(D-SAND) 3/2/2011 NOTE:View Schematic w/Alaska Schematic9.0 -ET 9/24/2012 NOTE:PROFILE MODIFICATION-PUMPED 2090 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 D-Sand Liner LEM,7,288.4 8/10/2013 NOTE: PROFILE MODIFICATION-PUMPED 3100 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 7,494.8 �' ' D-Send Liner HH;7,343.3- 7,611.8 }1 E11 ISO SLEEVE;7,707.0. Whipstock 8;7,707.0 WINDOW 8;7,707.0-7,722.0 I 4 B-Send Liner LEM;7,464.8- L' 7,862.5 - B-Send Liner HH;7,703.3- 7,893.8 ,703.37,893.8 i PRODUCTION;27.4-8,838.4 r SLOTS;8,883.09,7690 1 , i 1t- , 1 [I- 1 r SLOTS;10,068.0-11,682.0 r I IF ASand Slatted Liner;7,820.0 11,725.0\ • • Proposal for 1J-105L1 to 1J-103L1 B Sand MBE Treatment with RPPG 1J-105 tri-lateral injector was drilled & completed in 2007 with laterals in West Sak A, B, & D sands. 1J-105L1 B lateral has 4.5", L-80 slotted liner. Multiple MBE events have occurred in 1J-105L1. The first happened 4/5/12 from 1J-105L1 to 1J-103L1 producer. A 5/26/12 IPROF found a B MBE in at 9550' RKB taking all PWI. On 9/24/12, a 1J-105L1 Crystal Seal job sealed this MBE for -3 months. A 3/24/13 IPROF verified that the treated MBE at -9550' had reopened. On 8/10/13, a Crystal Seal retreatment was pumped, and this treatment lasted for -3 years until it failed on 3/9/16. An IPROF on 5/25/16 in 1J-105L1 showed a new MBE at -9750' RKB. Currently 1J-105 is configured for 'A and D only' lateral injection. The B lateral is currently isolated with a B Iso-Sly. 1J-105 is currently on injection to the A and D sands. The following procedure is proposed to seal off the new B MBE at 9750' RKB with RPPG (aka: Reformed Polymer Particle Gel) to return 1J-105L1 to PWI service. RPPG is a newly developed synthetic dehydrated crystalline particle polymer gel product that hydrates and swells in water. RPPG is like Crystal Seal in appearance and swellability. However, unlike Crystal Seal, RPPG has a delayed crosslinking feature that tightly bonds individual swollen particle polymer grains together into an amalgamated mass of gel after placement to the MBE. This crosslinking feature should give RPPG MBE treatments much better resilience to disaggregation and breakdown vs. Crystal Seal when the treatment in the MBE is being subjected to drawdown pressure from flowing the producer. Unlike previous Crystal Seal MBE treatments that we have performed to date in West Sak MBE's, we propose that we inject the initial 37 to 50 bbls of gel slurry at maximum concentration from CT to the MBE while drawdown is being applied on the MBE by flowing the 1J-103 offset producer. Coil Tubing Procedure: 1) RIH to pull the Iso-Sly set across the B LEM at 7707' RKB. 2) RIH to set an A Sand Isolation Plug in the 3.562" DB Nipple at 7809' RKB. 3) RIH to set a Type 1 B Diverter across in the B LEM at 7707' RKB. 4) RIH to set a Type 2 D Iso-Sly with verified 2.75" min ID across in the B LEM at 7348' RKB. 5) RIH to shoot 5' of 'big hole' perforations at 9750 - 9755' RKB across the new B MBE located at 9750' RKB, per 5/25/16 IPROF. 6) Put both 1E-103 producer and 1J-105 injector BOL 12 - 24 hrs before CTU RU on 1J-105. Have 1J-103 flowing to 1J test separator. This will reestablish flow through the B MBE between the wells. RU CTU with 2" CT on 1J-105. RIH with a down port nozzle on CT. Park nozzle at 9740' RKB just above the open MBE in 1J-105L1. Blend Seawater from transports with 1 - 4 mm mesh RPPG at 0.30 - 0.35 ppg slurry concentration `on-the-fly' in a mixing van and then pump it down CT at a steady established rate of 1.7 - 2.2 bpm while producing 1J-103 and injecting 1000 BPD PWI down CT x Tbg to keep CT back side flushed of any RPPG slurry. Pump the first 37 to 50 bbls of slurry out of the nozzle parked at MBE at 9740. After -37 bbls of slurry exits the nozzle, shut-in 1J-103 (to avoid any significant placement of RPPG to the producer), while continuing slurry pumping to 1J-105L1 and starting POOH at 50 fpm. Continue pumping steady rate and slurry concentration until nozzle is POOH and parked at `safety' above all liner slots at 8140' • • RKB. POOH to safety mitigates development of very heavy PU weight that often develops while pumping heavy gel concentrations into slotted liners with crossflow. Continue pumping slurry at steady rate and 0.30 - 035 ppg concentration until WHIP reaches -800 psi, then SI all 1J-105 injection to CT x Tbg annulus, and swap from RPPG slurry to pumping to 5 bbls of Seawater spacer down CT, followed by —62 bbls Diesel FP followed by 1 CT volume of CT Diesel FP. When Diesel starts going down CT, start POOH from safety while maintaining steady rate down CT. RD CTU. Wait 2 days for RPPG particles fully crosslink in MBE before returning 1J-105L1 to PWI. If step 6 is executed as planned, 1J-103 producer will be allowed to flow back to the plant with low odds that it would create a plant upset due to gel production. 7) RIH with jet swirl nozzle and tag top of RPPG in well, then jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner. POOH w/CT. PU & RIH with 2.5" OD CT Tractor with nozzle to jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner at deeper depths to open more lateral to PWI. POOH w/CT Tractor. Place 1 J-105L1 on PWI to evaluate the results of the MBE treatment. 8) RIH with IPROF BHA. Memory log down & up passes to verify all the MBE's are sealed off. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-105L1 to PWI service. Leave 1J-105L1 on 'B sand only' injection long enough to evaluate that the B MBE's remain sealed. When deemed appropriate, proceed to steps 9 -11 to normal up well. 9) RIH to pull the Iso-Sly across the D LEM at 7348' RKB to open the D lateral to injection. 10) RIH to pull the Diverter in the B LEM at 7707' RKB and leave B lateral open to injection. 11) RIH to pull the Plug from the DB Nipple at 7809' RKB to open the a lateral to injection. Return 1J-105 to PWI service to all 3 laterals. • KL l la P7 z6-162-7 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> i Z I Sent: Saturday, December 10, 2016 8:26 AM '\ To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr; NSK Optimization Engr; CPF1 DS Operators; Targac, Gary; Sullivan, Michael; Krysinski, Marina L Subject: LPP/SSV Returned to Service on Well 1J-105 Jim, The low pressure pilot(LPP) on well J-105 (PTD#207-027 207-028 and 207-029) was returned to service and removed from the safety defeat log on 12/02/2 16.7 atterthe well was shut-in. The LPP had originally been defeated since 11/18/2016. 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 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 Email: n1638conocophillips.com SCANNED MAY (,,r 1 KCcA I J 05- Pit SPit Z-07v-70 Regg, James B (DOA) From: Regg, James B (DOA) (Re I �' I k' Sent: Monday, November 21, 2016 8:28 AM � To: 'NSK West Sak Prod Engr' Subject: RE:The LPP/SSV for well 1J-105 was defeated on 11/18/2016 Corrected Permit Us —should be 2070270, 2070280, and 2070290 Jim Regg Supervisor, Inspections ,!I`. AOGCC SCANNED 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Friday, November 18, 2016 5:55 PM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com>; CPF1&2 Ops Supt<n2073@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF1 DS Operators<n1275@conocophillips.com>; Targac, Gary <Gary.Targac@conocophillips.com>; Sullivan, Michael<Michael.Sullivan@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; Effiong, Michael <Michael.Effiong@conocophillips.com> Subject:The LPP/SSV for well 11-105 was defeated on 11/18/2016 Jim, The low pressure pilot(LPP) on West Sak injector 1J-105 (PTD#207-270, 207-280 and 207-290) was defeated today, 11/18/2016, after the well head injection pressure dropped below the LPP set point of 250 psi. 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 250 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. Kind Regards, Scott Stanley / Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 1 2C.9 ciC4 Cc MAR 2 2 nib ,yy�� � WELL LOG TRANSMITTAL#903089770 `4, G�.X To: Alaska Oil and Gas Conservation Comm. March 11, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 . BENDEREo C+; ,A M.K. scANNEn �. .. RE: Injection Profile with RMT3D: 1J-105 Run Date: 1/28/2016 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@hallibutton.com 1.1-105 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-23346-00 Injection Profile with RMT3D (Field print) 1 Color Log 50-029-23346-00 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:MAtga4z4L,"/)_jaeweareet Image Projeet Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned duri ng a special rescan activity or are viewable by direct inspection of the file. ~C~- Q~~, ~ Well History File Identifier ~ ~~ ~ ~~~ ~~ ~~ ~ !~ ( ~ ~~~ ~ ~~ ~ ~~ ~~~ ~~ ~~ ~ ~~ ~~ ~ Qrganizing (done) Two-sided ^ Rescan Needed RESGAN DI ITAL DATA It C l ~ OVERSIZED (Scannable) o or ems: Diskettes, No. , ,, ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: BY: f Maria Date: OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Project Proofing BY: Mari Scanning Preparation BY: Maria Production Scanning _~P uiiiiiiiiisillli /s/ + -~ =TOTAL PAGES ~ / (Count does not include cover sheet) /~ /s/ ~/ Stage 1 Page Count from Scanned File: _~~ (Co~mt does include cover sheet) Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: ~ ~~~~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO /s/ ~~ NO "fiuuuuiiiiiiu Res~,~~ed iuumiimiim BY: Maria Date: /s/ Comments about this file: Quality Checked I~I II'III ~~~ I~~I (~~ Date: (. x30= Date: ((~/g~~ P 10!6/2005 Well History File Cover Page.doc iceu L -(cs prt 74770Z7o Regg, James B (DOA) From: NSK West Sak Prod Engr[n1638 @conocophillips.com] Sent: Sunday, October 13, 2013 5:36 PM erl U1(4 (1 3 To: Regg, James B (DOA) f Cc: CPF1 DS Lead Techs; CPF1,Ops Supv; NSK Problem Well Supv; NSK Optimization Engr; Seitz, Brian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; CPF1 Prod Engr; Jensen, Marc D Subject: LPP/SSV Returned to service on 1E-102, 1E-105, and 1J-105 10/13/13 Jim, The low pressure pilots (LPP) on the following injectors were returned to service on Oct 13, 2013 when the well head injection pressures exceeded 500 psi: • 1E-102 (PTD#204-231, 204-232) • E-105 PTD#205-006 20 -107 205-008) • 1J-105(P ' . '7-027 207-028 and 207-129) ' This note is in reference to "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Amanda Patterson /Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. (907)659-7234 Pager 497 SCANNED DEC 2 3 2013 OF 7'4 ww * 8 I% %es THE STATE Alaska Oil and Gas ® f l LAS Conservation ommissio 1 GOVERNOR SEAN PARNELL 333 West Seventh Avenue 04, AL fi ° AS p, Anchorage, Alaska 99501 -3572 Le Main: 907.279.1 433 Fax: 907.276.7542 John Peirce Wells Engineer SCANNED MAY 1 0 2013 ConocoPhillips Alaska, Inc. P.O. Box 100360 f Qo� Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J -105 Sundry Number: 313 -227 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, , Cathy P. oerster Chair DATED this 'U day of May, 2013. Encl. • .1 ,. g cif STATE OF ALASKA g¢ ..� A•KA OIL AND GAS CONSERVATION COMI•ION 0,75 S / /._.3 APPLICATION FOR SUNDRY APPROVALSr J`"' OR 20 AAC 25.280 �/ � �� O — / 1. Type of Request: Abandon r Rug for Redrill ("-' Perforate New Pool ("" Repair w ell E AthatiWCFYogram ('""` Suspend I Plug Perforations r Perforate (" Pull Tubing r Time Extension "° Operational Shutdow n r Re -enter Susp. Well E Stimulate r Alter casing Other:Crystal Seal MBE i� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory r 207 - 027P 3. Address: Stratigraphic r Service n 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23346 - 00 n 7. If perforating, Gel . Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes F No I✓ 1J - 105 n 9. Property Designation (Lease Number): ?al lb 10. Field /Pool(s): ADL 25662 , I I 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): 11735 d 3823 W 11725' 4 3823' m none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3356 10.75 3387' 2254' WINDOW D 8811 7.625 8838' 3820' WINDOW B 3905 4.5 11725' 3823' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8863' 9769', 10068' - 11682' o 3821' 3816', 3810' - 3822' 4.5 L - 80 7324 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - ZXP LINER TOP PACKER MD= 7289 TVD =3638 s PACKER - ZXP LINER TOP PACKER MD= 7465 TVD =3658 G PACKER - BAKER 'HRD' ZXP LINER TOP PACKER MD= 7820 TVD =3719 NIPPLE - CAMCO 'DB' NIPPLE MD =498 TVD =498 D 12. Attachments: Description Summary of Proposal F, • 13. Well Class after proposed work: Detailed Operations Program I — BOP Sketch 1 — Exploratory E Stratigraphic r Development r Service 9 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil I Gas I — WDSPL r Suspended E 16. Verbal Approval: Date: VVINJ IW GINJ I WAG I`" Abandoned E Commission Representative: GSTOR E SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Email: John.W.Peirce Printed Name John Peirce Title: Wells Engineer Signature ? Phone: 265-6471 Date r7/1 3 Commission Use Only Sundry Number: 313 -227 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test E Mechanical Integrity Test E Location Clearance E RBDMS MAY 1 0 201K) Other: Spacing Exception Required? Yes ❑ No 121 Sibsequent Form Required: / c — 4-16I /, � � / APPROVED BY '1 / +� MI OER TH OM ISSION Date: 5 — l0 - ! „3 Approved by: `I' , p�.vcd application is vaioTor iz m from the Edatc oT approval. Form 10 -403 (Revised 10/2012) VLJ Submit Form and Attachments in Duplicate � NO 3 /i3 ORIGINAL s % t • • 1J -105L1 to 1J -103L1 `B' MBE Crystal Seal Retreatment A Matrix Bypass Event (MBE) occurred on 4 -5 -12 in 1J -105L1 in the B sand lateral. A 5 -26 -12 (PROF saw the B MBE at 9550' RKB behind the 4.5" slotted liner. Almost all PWI was exiting the slotted liner at this MBE. A 9 -25 -12 Crystal Seal treatment sealed the B MBE, but the treatment broke down within a few months that resulted in shut -in of PWI to 1J-105. A 3 -24 -13 (PROF in 1J -105L1 confirmed the B MBE at —9550' RKB Crystal Sealed 9 -25 -12 was once again open taking all PWI. The 1J 105L2 D lateral was isolated with an Iso Slv on 5-23-12 -12 (for 9 -25 -12 B MBE Crystal Seal treatment), and the D Iso- Sleeve remains set. 1J-105 is configured to perform a 1J -105L1 B MBE Crystal Seal retreatment. The B Diverter remains set. It is proposed that 1J -105L1 B MBE will be resealed with Crystal Seal pumped down coil tubing. No well work needs to be done to prepare for 1J-105L1 for a retreatment. Large hole perforations already exist in 1J -105L1 across the B MBE, which were shot prior to pumping the initial B MBE treatment. A post - Crystal Seal IPROF will likely be run in 1J -105L1 to verify success of the job. Coil Tubing Procedure: RIH with either a large down port or side port nozzle on 2 "coil tubing. Park nozzle across the large hole perforation interval at 9540 - 9545' RKB in the 4.5" slotted liner just above the MBE at 9550' RKB. Pump a Crystal Seal retreatment as follows: a) Seawater down coil. Determine a steady treatment rate (likely between 1.5 - 2 bpm) to be held constant during the treatment through Flush (step f) to monitor MBE response to treatment and to note a CrystalSeal screenout during slurry pumping. Swap from Seawater to 2% KCI, b) 2% KCI Water with 0.05 ppg Crystal Seal (we will use 4 mm mesh for all stages b through e) down coil. Each stage volume is TBD during pumping based on the treating pressure response seen during stage. When called, continue pumping, c) 2% KCI Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if we see screen out. d) 2% KCI Water w /0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCI Water w /0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out is seen, open CT x Tbg annulus to return tank, and pump 1 CT volume Seawater Flush to displace Crystal Seal slurry from coil to well while POOH. If screen out has not been seen prior to Flush, leave CT x Tbg annulus SI and pump 1 full CT volume of Seawater Flush to displace remaining Crystal Seal Slurry from coil to liner while POOH to D LEM, then swap to pumping Diesel FP down coil, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let Crystal Seal become fully swollen and seal off the MBE before returning 1J-105L1 to PWI for treatment evaluation. Coil tubing will be used to perform a post - CrystalSeal treatment tag, a possible Crystal Seal cleanout, and a memory IPROF depending on post -job PWI and offset producer responses. s yy� KUP • 1J -105 Conoc l� Well Attributes Max Angle & MD TD Alaska. Ilu.; Wellbore APUUWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) 500292334600 WESTSAK INJ 9296 9,846.46 11335.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date "' - SSSV: NIPPLE Last WO: 32.29 4/29/2007 Well Confq' -1J-105, 10/262012 10:02:22 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date - - -- -- Last Tag: c. Rev Reason: CORRECT PERF DATA osborl 10/26/2012 HANGER, 23 _ Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd �--", SURFACE 103/4 9.950 30.5 3,386.8 2,253.4 45.50 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, WINDOW D 30 8 7.000 7,348.0 7,363.0 3,647.2 NIPPLE, 498 i. Casing Description String 0... String ID ... Top (ftKB) Set Depth (L., Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT, WINDOW B 8 7.000 7,707.0 7,722.0 3,703.3 2,268 i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 75/8 6.875 27.4 8,838.4 3,820.1 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE, .y� � D - Sand Liner LEM 4 1/2 3.958 7,288.5 7,494.8 3,665.0 12.60 L - 80 IBTM 30 -3,387 Liner Details GAS LIFT, Depth 6,394 r (TVD) Top Inc! Nomi... � _ J j Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) SLEEVE - C, ( • 7,288.5 3,638.1 83.19 PACKER L2 D LEM ZXP 5 x 7 - 5/8" Liner Top Packer TOP 4.940 6,891 7,307.5 3,640.2 82.98 CSR L2 D LEM Casing SBR 109 C 6.26" OD x 4.75" ID 4.750 LOCATOR, , .... 7,327.1 3,642.5 82.76 BUSHING L2 D LEM Reducing XO Bushing 5 Hydril 563 x 4 - 1/2" IBT 3.930 SEAL ASSY, 7,297 7,332.4 3,643.2 82.70 HANGER L2 D-SAND LEM Above Hook Hanger 3.960 7,343.3 3,644.6 82.58 HANGER L2 D -SAND LEM Inside Hook Hanger 3.688 II I1 ISO SLEEVE, 7,491.5 3,664.2 77.81 SEAL ASSY L2 D -SAND LEM Baker Seal Assembly 4 -1/2" STL Box up 3.860 7,343 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd Whipstock D, D - Sand Liner HH 4 1/2 3.476 7,343.3 7,611.8 3,686.8 11.60 L - 80 BTC 7,347 WINDOW D, Liner Details 7,348 -7,363 Top Depth (TVD) Top Incl Nomi... Top (ttKB) (ftKB) ( Item Description Comment ID (in) 7,343.3 3,644.6 82.58 HANGER L2 D -SAND HOOK ASSY Baker Model 8-1 Hook Hanger 75/8" x 4 1/2" 5.600 (Inside csg) D - Sand Liner 7,360.0 3,646.8 82.39 HANGER L2 D -SAND HOOK ASSY Baker Model 13-1 Hook Hanger 75/8" x 4 1/2" 4.000 LEM, 7,288 - 7,495 (Outside csg) 7,505.3 3,667.3 78.19 ECP L2 D -SAND HOOK ASSY Baker Payzone Extemal Casing Packer 3.960 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd B - Sand Liner LEM 4 1/2 3.958 7,464.8 7,862.5 3,725.4 12.60 L - 80 IBT D-Sand Liner Liner Details H Top Depth 7,343 -7,812 12 (TVD) Top Inel Nomi... DIVERTER, Top (ftKB) MB) (°) Rem Description Comment ID (!n) 7.703 7,464.8 3,657.7 77.08 PACKER L1 B - SAND LEM ZXP 5 x 7 - 5/8" Liner Top Packer TOP 4.767 Whipstock B, 7.707 7,483.8 3,662.4 77.60 CSR L1 B - SAND LEM 109 Casing SBR 6.26" OD x 4.75 4.750 WINDOW B, 7,707 7,503.5 3,666.9 78.14 BUSHING L1 B -SAND LEM XO Bushing 5-1/2" Hydril 563 x 4 -1/2" IBT 3.958 7,696.5 3,699.4 81.21 HANGER L1 B -SAND LEM LEM Above Hook Hanger 3.688 7,703.3 3,700.4 81.18 HANGER L1 B -SAND LEM LEM Inside Hook Hanger 3.688 7,809.3 3,717.1 80.49 NIPPLE L1 B -SAND LEM Camco "DB-6" Nipple, I.D. 3.562 ", IBT 3.562 Nom 7,859.2 3,724.9 81.40 SEAL ASSY 11 B -SAND LEM Baker Seal Assembly 4 -1/2' STL Box up 3.860 ° Casing Description String 0... String ID ... Top (ttKB) Set Depth ( f... Set Depth (ND) ... String Wt... String ... String Top Thrd " I B - Sand Liner HH 4 1/2 3 I 7 I 7 3 i 11 I L -80 I BTC Bland Liner : " Liner Details LEM, - Top Depth 7,465 -7,862 A ITVD) Top Intl Nomi... Top (ftKB( (ftKB) ( °) Item Description Comment ID (!n) 13 Liner I 7,703.3 3,700.4 81.18 HANGER L1 B - SAND Baker Model 13 Hook Hanger 7 5/8" x 4 1/2' (Inside) 5.640 HH, 7,703 - 7,894 7,720.0 3,703.0 81.08 HANGER L1 B - SAND Baker Model B Hook Hanger 75/8" x 4 1/2' (Outside) 5.640 PRODUCTION, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 27A,838 A -Sand Slotted Liner 4 1/2 3.476 7,820.0 11,725.0 3,822.7 11.60 L -80 BTC w/ TR Liner Details Top Depth (ND) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) 7,820.0 3,718.8 80.68 PACKER A -SAND 5.5 "x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.500 SLOTS, 7,839.0 3,721.8 81.03 SEAL NIPPLE A -SAND "RS" Packoff Seal Nipple, 6.07" OD / 4.87' ID 4.870 8,863 - 9,769 7,841.8 3,722.2 81.08 HANGER A -SAND 5.5" X 7.63" "Flex- Lock" Liner Hgr, 6.59" OD/ 4.85" ID 4.850 7,851.6 3,723.7 81.26 SBE A -SAND 190-47 Seal Bore EM, 6.29" OD /4.75" ID 4.750 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.992 23.0 7,323.9 3,642.1 12.60 L -80 IBT Completion Details Top Depth (TVD) Top lncl Nomi... Top (ftKB) (ftKB) 1 ° ) Item Description Comment ID (in) 23.0 23.0 -0.04 HANGER TUBING HANGER w/ PUP 3.992 498.3 497.7 7.11 NIPPLE CAMCO DB NIPPLE 3.875 6,691.3 3,494.6 69.09 SLEEVE -C CMU SLIDING SLEEVE (CLOSED ON 6/29/2007) 3.812 7,295.5 3,638.9 83.11 LOCATOR LOCATOR 3.880 7,296.6 3,639.0 83.10 SEAL ASSY GBH -22 LOCATING SEAL ASSEMBLY 3.880 10,068-11,682 - Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top(ftKB) MB) ( °) Description Comment Run Date ID (in) 7,343.0 3,644.5 82.58 ISO SLEEVE ISO SLEEVE 5/23 /2012 2.500 Itandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ttKB) (ftKB) 11 Make Model (in) Sery Type Type (in) (psi) Run Date Corn... A - Sand Slotted 1 2,267.8 1,853.7 69.17 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/28/2007 Liner, 2 6,393.7 3,387.3 68.93 CAMCO KBMG 1 GAS LIFT DMY BEK -5 0.000 0.0 4/28/2007 7,820.11,725 TD (1J -105), - 11,735 KUP 1J -105 ConocoPhilliips Os Alaska. Inc cu000Pfallpe KB -Grd (ft) Rig Release Date 32.29 4/29/2007 Well Oen' - -1 J -105 10/262012 AM Ohetaatlo- Actual +PflcEs.23 " Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Intl Top (ftKB) (ftKB) (') Description Comment Run Date ID (in) 7,347.0 3,645.0 82.54 Whipstock D D-SAND WHIPSTOCK 4/22/2007 CONDUCTOR, 7,703.0 3,700.4 81.18 DIVERTER 5/23/2012 2.750 30 - 10.198 NIPPLE, 08 • 7,707.0 3,701.0 81.16 Whipstock B B WHIPSTOCK 4/9/2007 ' GAS LIFT, 2,268 O ' Perforations & Slots .per. Shot Top (TVD) Btm (TVD) Dens SURFACE, Top (ftKB) Btm (ftKB) (ftKB) (RKB) Zone Date (eh— Type Comment 30 - 3,387 8,863.0 9,769.0 3,821.1 3,816.0 WS A2, 1J -105 4/26/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long _ x .125" wide GAS LIFT, '. 8,394 - 10,068.0 11,682.0 3,809.7 3,822.4 WS A2, 1J - 105 4/26/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long N�a x .125" wide SLEEVE -C, 6,891 r Notes: General & Safety LOCATOR. _ End Date Annotation 7,296 eiNteNtle 4/29/2007 NOTE: MULTI - LAT WELL - 1J - 105 (A SAND), 1J - 105L1 (B SAND), 1J - 10512 (D - SAND) SEAL ASSY, 7,297 3/2/2011 NOTE: View Schematic w/ Alaska Schematic9.0 ISO SLEEVE, 7,343 Whipstock 0, 7,347 WINDOW D, 7,348-7,383 I 1 D -Sand Liner 5 ` p LEM. ® a 7,288 -7,495 D -Sand Liner M 7,343 -7,612 12 DIVERTER. 7,703 - Whipstock B, 7,707 WINDOW B, 7,707 -7,722 NEM • y A. I 1 1, 13-Sand Liner 1 LEM, MOM 7,485 -7,862 A =Eli y B -Sand Liner NH. 7,703 -7,894 PRODUCTION, 27 -8,838 SLOTS, 8,883 -9,769 SLOTS, 10,068- 11,682 ASand Slotted Liner, 7,820-11,725 TD (1J -105), 11,735 • STATE OF ALASKA ALA* OIL AND GAS CONSERVATION COMilkION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well `-° Rug Perforations r Perforate r Other MBE Treatment Alter Casing r Pull Tubing [ Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well "" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 207 -027 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic �' Service ,. 50 - 029 - 23346 - '-- 7. Property Designation (Lease Number): 8. Well Name and Number: , ADL 25661, 25662 " 1J 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 11735 feet Plugs (measured) None true vertical 3823 feet Junk (measured) None Effective Depth measured 11725 feet Packer (measured) 7289, 7465, 7820 true vertical 3823 feet (true vertucal) 3638, 3658, 3719 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108 SURFACE 3356 10.75 3387 2254 PRODUCTION 8811 7.625 8838 3820 A -SAND SLOTTE 3905 4.5 11725 3823 r °' OCT 2 3 201? Perforation depth: Measured depth: '8863'-9769', 10068'- 11682' SCANNED JAN 2 8 2013, 6 0G True Vertical Depth: 3821'- 3816', 3810' -3822' Tubing (size, grade, MD, and TVD) 4.5, L -80, 7324 MD, 3642 TVD Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PACKER @ 7289 MD and 3638 TVD PACKER - ZXP LINER TOP PACKER @ 7465 MD and 3658 TVD PACKER - BAKER 'HRD' PACKER @ 7820 MD and 3719 TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): see attached summary 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 717 14. Attachments 15. Well Class after work: .. Copies of Logs and Surveys run Exploratory r Development r Service 17 Stratigraphic r 16. Well Status after work: Oil r Gas I WDSPL J Daily Report of Well Operations XXX GSTOR n WINJ P WAG r 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: 312 -270 Contact John Peirce as 265 -6471 Email: John .W.Peirce @conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date / 4 / I' �. 10/2_2.11,2_ n , 4Y 2 ' ? Form 1 -4 Revsed 12/201 0MS OCT 2 3 2012 /o - al- /� Submit Original Only 1J -105 Well Work Summary DATE SUMMARY 9/24/12 PERFORATED FROM 9540' T1 CTMD, OPENED CIRC SUB AND PLINED A TOTAL OF 2090 POUNDS CRYSTAL SEAL. PUMPED 440 POUNDS AT .1 PPG, 770 POUNDS AT .15 PPG v 405 POUNDS AT .2 PPG. AND 495 POUNDS AT .29 PPG. WELL FREEZE PROTECTED TO 2000' TVD. JOB COMPLETE. 10/8/12 DRIFTED TO 7325' SLM (AT/ NEAR D SAND ISO SLEEVE @ 7343' RKB) WITH 2.65" CENTRALIZER & 2.25" BAILER. COMPLETE. KUP 1J -105 ConocoPhillips 01 Well Attributes Max Angle & MD TD s a A{aska. lrl,.; Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) 500292334600 WESTSAK INJ 92.96 9,846.46 11,735.0 mpsi "" Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: NIPPLE Last WO: 32.29 4/29/2007 Well Cootie -1J -105. 1033/2012 52 PM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: ADD PERFS ninam 10/13/2012 HANGER, 23 - : " Casing Strings 1 1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f.. Set Depth (TVD) .. String Wt... String String Top Thrd -- CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd --: SURFACE 103/4 9.950 30.5 3,386.8 2,253.4 45.50 L - 80 BTC CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 30 WINDOW D 8 7.000 7,348.0 7,363.0 3,647.2 NIPPLE, 498 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT. t WINDOW B 8 7.000 7,707.0 7,722.0 3,703.3 2,288 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 7 " PRODUCTION 7 5/8 6.875 27.4 8,838.4 3,820.1 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, 30 FACE, D - Sand Liner LEM 4 1/2 3.958 7,288.5 7,494.8 3,665.0 12.60 L - 80 IBTM • Liner Details GAS LIFT, Top Depth 6.394 (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) SLEEVE -C, 62697 7,288.5 3,638.1 83.19 PACKER L2 D - SAND LEM ZXP 5 x 7 - 5/8" Liner Top Packer TOP 4.940 LOCATOR, y)� SEAL ASSY, 7,307.5 3,640.2 82.98 CSR L2 D -SAND LEM Casing SBR 109-47 C 6.26" OD x 4.75" ID 4.750 7,29 s. 7,327.1 3,642.5 82.76 BUSHING L2 D -SAND LEM Reducing XO Bushing 5-1/2" Hydril 563 x 4 -1/2" IBT 3.930 7'297 7,332.4 3,643.2 82.70 HANGER L2 D -SAND LEM Above Hook Hanger 3.960 7,343.3 3,644.6 82.58 HANGER L2 D-SAND LEM Inside Hook Hanger 3.688 SLEEVE, 7,343 7,491.5 3,664.2 77.81 SEAL ASSY L2 D -SAND LEM Baker Seal Assembly 4 -1/2" STL Box up 3.860 I Whipstock D, Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 7,347 D - Sand Liner HH 1 4 1/2 I 3.476 I 7,343.3 I 7,611.8 3,686.8 I 11.60 I L - 80 BTC WINDOW S. 7,348 -7,363 Liner Details • I Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 7,343.3 3,644.6 82.58 HANGER L2 D -SAND HOOK ASSY Baker Model B-1 Hook Hanger 75/8" x 4 1/2" 5.600 W (Inside csg) D - sand Liner LEM, 7 3,646.8 82.39 HANGER L2 D -SAND HOOK ASSY Baker Model B-1 Hook Hanger 7 58" x 4 1/2" 4.000 7,288 ___ (Outside csg) 7,505.3 3,667.3 78.19 ECP L2 D -SAND HOOK ASSY Baker Payzone External Casing Packer 3.960 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1411 B -Sand Liner LEM I 4 1/2 I I 3.958 7,464.8 7,862.5 3 ,725.4 I 12 L - 80 IBT D -sand Liner Liner Details 7,343 -7,872 Top Depth DIVERTER, (ftKB) Top Intl N 7,703 \ Top (ftKB) ( ) ( °) Item Description Comment ( ) Whipstock B, 7,464.8 3,657.7 77.08 PACKER L1 B - SAND LEM ZXP 5 x 7 - 5/8" Liner Top Packer TOP 4.767 7,707 WINDOW 6, 7,483.8 3,662.4 77.60 CSR L1 B LEM 109 Casing SBR 6.26" OD x 4.75 4.750 7,707 - 7,722 7,503.5 3,666.9 78.14 BUSHING L1 B -SAND LEM XO Bushing 5-1/2" Hydril 563 x 4 -1/2" IBT 3.958 7,696.5 3,699.4 81.21 HANGER L1 B -SAND LEM LEM Above Hook Hanger 3.688 7,703.3 3,700.4 81.18 HANGER Lt B -SAND LEM LEM Inside Hook Hanger 3.688 7,809.3 3,717.1 80.49 NIPPLE L1 B -SAND LEM Camco "DB -6" Nipple, I.D. 3.562 ", IBT 3.562 t� 7,859.2 3,724.9 81.40 SEAL ASSY L1 B -SAND LEM Baker Seal Assembly 4 -1/2' STL Box up 3.860 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd t ', - T i B -Sand Liner HH 4 1/2 3.476 7,703.3 7,893.8 3,730.0 11.60 L-80 BTC e -sand Liner r Liner Details L862 i Top Depth 7,465 -7,862 ' (TVD) Top Intl Nomi... 13-Sand Liner Top (ftKB) (ftKB) (°) Item Description Comment ID (!n) HH, i 7,703.3 3,700.4 81.18 HANGER L1 B - SAND Baker Model B Hook Hanger 75/8" x 4 1/2' (Inside) 5.640 7,703 - 7,694 . PRODUCTION, 7,720.0 3,703.0 81.08 HANGER L1 B - SAND Baker Model B Hook Hanger 75/8" x 4 1/2' (Outside) 5.640 27 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd A -Sand Slotted Liner 4 1/2 I 3.476 7,820.0 11,725.0 3,822.7 11.60 L -80 BTC w/ TR Liner Details Top Depth (TVD) Top Inc! Noml... Top (ftKB) (6KB) ( °) Item Description Comment ID (In) SLOTS. 7,820.0 3,718.8 80.68 PACKER A -SAND 5.5 "x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.500 8.863 - 9,769 7,839.0 3,721.8 81.03 SEAL NIPPLE A -SAND "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.870 7,841.8 3,722.2 81.08 HANGER A -SAND 5.5" X 7.63" "Flex- Lock" Liner Hgr, 6.59" OD/ 4.85" ID 4.850 IPERF, 9.540 - 9545 7,851.6 3,723.7 81.26 SBE A -SAND 190-47 Seal Bore Ext, 629" OD / 4.75" ID 4.750 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.992 23.0 7,323.9 3,642.1 12.60 L -80 IBT Completion Details Top Depth (TVD) Top Inc! Nonni... Top (MB) MB) (1 Rem Description Comment ID (!n) 23.0 23.0 404 HANGER TUBING HANGER w/ PUP 3.992 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (7n) (psi) Run Date Com... SLOTS, 1 2,267.8 1,853.7 69.17 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/28/2007 10.068 2 6,393.7 3,387.3 68.93 CAMCO KBMG 1 GAS LIFT DMY BEK -5 0.000 0.0 4/28/2007 A -Send Slotted Liner, 7 7,620 - 17.725 5 TD (11705), 17,735 • - n KUP 1J-105 .. . Conoc 0;- Alaska. Inc .................. . ggs KB-Grd (ft) Rig Release Date °" 32.29 4/29/2007 Well Confl9' - J -105, 10/13/20123'15'52 PM Schematic -AGUaI HANGER, 23- , I t - - Completion Details Top Depth (TVD) Top Inc! Noml... Top (ftKB) (ftKB) (1 Item Description Comment ID (!n) . 498.3 497.7 7.11 NIPPLE CAMCO DB NIPPLE 3.875 CONDUCTOR, 6,691.3 3,494.6 69.09 SLEEVE -C CMU SLIDING SLEEVE (CLOSED ON 6/29/2007) 3 ___r- 30 - 108 NIPPLE,498 %M. 7,295.5 3,638.9 83.11 LOCATOR LOCATOR 3.880 mop GAS LIFT, _ 7,296.6 3,639.0 83.10 SEAL ASSY GBH -22 LOCATING SEAL ASSEMBLY 3.880 2,268 �- r Other In Hole (INireline retrievable plugs, valves, pumps, fish, etc.} Top Depth SURFACE, (TVD) Top Inc! 30 -3,38] Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (!n) 7,343 3,644.5 82.58 SLEEVE ISO SLEEVE 5/23/2012 2.500 GAS LIFT, 6,394 7,347 3,645.0 82.54 Whipstock D D-SAND WHIPSTOCK 4/22/2007 SLEEVE 7,703 3,700.4 81.18 DIVERTER 5/23/2012 2.750 6.891 7,707 3,701.0 81.16 Whipstock B B -SAND WHIPSTOCK 4/9/2007 LOCATOR, x96 a War SEAL ASSY, .6 Perforations & Slots 7,297 �l Shot Top (TVD) Btm (TVD) Dens I I Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ( Type Comment 8,863 9,769 3,821.1 3,816.0 WS A2, 1J - 105 4/26/2007 32.0 SLOTS Alternating solid /slotted pipe 2.5" long SLEEVE, 7,343 x .125" wide 7,3 Whipstock D, 47 9,540 9,545 3,816.7 3,816.7 WS B, 1J -105 9/24/2012 IPERF WINDOW D, 10,068 11,682 3,809.7 3,822.4 WS A2, 1J -105 4/26/2007 32.0 SLOTS Alternating solid /slotted pipe 2.5" long 7,348 - 7,363 x .125" wide Notes: General & Safety End Date Annotation 4/29/2007 NOTE: MULTI -LAT WELL- 1J -105 (A- SAND), 1J -105L1 (B- SAND), 1J -105L2 (D -SAND) 0-Sand Liner a i g F 3/2/2011 NOTE: View Schematic w/ Alaska Schemetic9.0 LEM, 7,288-7A95 AMC C ' D -Sand Liner H 7 it ,343 -7,612 12 DIVERTER, 7,703 Whipstock B, 7.707 � WINDOW B, 7,707 -7,722 BM - 1 1 I) B -Sand Liner ' / I LEM, 7,465 -7,862 y_ B -Sand Liner HH, 7,703 -7,894 PRODUCTION, 27 -8,838 SLOTS, 8,863 -9,769 IPERF, 9,540 -9,545 SLOTS, 10,068 - 11,682 A -Sand Slotted Liner, 7,820- 11,725 TD (1J- 105), 11.735 • • k:iP & 1_1 o s PL zo 70z -7Q Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, October 03, 2012 4:33 PM To: 'Patterson, Amanda' ((( Subject: RE: LPP /SSV Defeated for 1J -105 on 10/03/2012 PTD #s are 2070270, 2070280, 2070290 Jim Regg AOGCC f, 333 W. 7th Ave, Suite 100 SCANNED APR 0 8 2013 Anchorage, AK 99501 907- 793 -1236 From: Patterson, Amanda mailto: Amanda.Patterson@a�conocophilli s.com] [ p Sent: Wednesday, October 03 c Ot , 2012 2:27 PM To: 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; CPF1 Prod Engr Subject: LPP /SSV Defeated for 13-105 on 10/03/2012 Jim, The low pressure pilot (LPP) on injector 1J -105 (PTD# 207 -270, 207 -280 and 207 -290) was defeated on 10/03/2012 when the injection pressure fell below 500 PSI after putting the well back on injection. Prior to bringing the well online, it had been shut in since 4/30/12 due to an MBE that has since been treated. The wellhead injection pressure is currently 153 psi and the injection rate is 294 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. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 Cell: (281) 796 -5044 1 • i [F [Fl Li A EL ,As.A SEAN PARNELL, GOVERNOR fki, ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 279-1433 99501-3539 PHONE (907) FAX (907) 276-7542 John Peirce Wells Engineer AUG 3 e' 202 ConocoPhillips Alaska, Inc. AUG 1 OX P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105 Sundry Number: 312-270 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, 1 , Cathy P. oerster Chair At-- DATED this z.--) c day of July, 2012. Encl. • STATE OF ALASKA RECEIVED A,KA OIL AND GAS CONSERVATION COMMION APPLICATION FOR SUNDRY APPROVALS JUL 2 3 2912 20 AAC 25.280 nr Z /2 s��lZ- 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change �ip IbOet'Mrhf r Suspend r Plug Perforations r Perforate r Pull Tubing r N g Mme Extension r- Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing O ther•L:ystel - 9cM - Treatmd - v7 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Explorator r 207 - 027 • 3. Address: Stratigraphic r Service p- . 6. API Number P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23346 - 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 r No IV 1J -105 , ( At 4 /ti' i3e.i 9. Property Designation (Lease Number): , 10. Field /Pool(s): ADL 25661, 25662 Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11735 • 3823 ' 11725' 3823' Casing Length Size MD ND Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3356 10.75 3387' 2254' PRODUCTION 8811 7.625 8838' 3820' A -SAND SLOTTED LINER 3905 4.5 11725' 3823' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8863' 9769', 10068' 11682' 3821' 3816', 3810' - 3822' 4.5 L - 7324 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - ZXP Liner Top Packer MD =7289 ND =3638 PACKER - ZXP Liner Top Packer MD =7465 ND= 3658 PACKER - Baker HRD ZXP Liner Top Packer MD =7820 TVD =3719 NO SSSV 12. Attachments: Description Summary of Proposal PI 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Development r Service ` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/17/2012 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ J. GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature idFrtn j ,�, , - Phone: 265 -6471 Date 7/ . / _ . Commission Use Only Sundry Number: ^I 2 z--- Conditions of approval: Notify Commission so that a representative may witness ���//J"' Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance J Other: Subsequent Form Required: / ° L/ G / APPROVED BY Approved by: COMMISSIONER THE COMMISSION DaterZ$ (a-- 'f `!I/ �B 7-L4 - l - Form 10 -403 Rev ed 1/20 0 D �S JUL 2 6 2011 `r Submit in Duplicate ; , "/ OR INALy/�- • 1J -105L1 to 1J -103L1 MBE Treatment A 1J-105 to 1J-103 producer Matrix Bypass Event (MBE) occurred 4- 05 -12. On 4- 29 -12, a main -bore IPROF showed all PWI entering 1E-105L1 B lateral with heavy cross flow from the D to B lateral. On 5- 26 -12, a CT IPROF in the B lateral to 11500' CTMD showed a large B MBE present at +/- 9550' CTMD taking almost all the PWI. It is proposed that the B MBE be sealed with Crystal Seal. This product is used for treating `/ injectors to restore water flood efficiency by sealing highly conductive communication flow paths through formation to offset producers. Crystal Seal is a water swellable dehydrated crosslinked synthetic gel polymer that can be placed in large formation void features (ie: MBE's) by mixing and pumping it as slurry in saline aqueous solutions. Crystal Seal granules may swell to hundreds of times initial size by hydrating and absorbing water, but swollen particles are too large to enter matrix pore throats, so the product does not result in skin damage to formation. Coil Tubing Procedure 1) RIH with 2" x 7' OAL Dummy TCP Gun drift assembly on 2" CT. Drift the BHA to 7800' RKB through the B Diverter set at 7707' RKB. POOH with drift assembly. RD CT. 2) RIH with 2" OD x 5' TCP gun (7' OAL). Park the pert gun and pump a ball down CT to fire the gun at 9540 - 9545' RKB. This location is at the middle of a 42' slotted joint across the MBE at 9550' RKB. Flag pipe to locate a nozzle later to pump Crystal Seal. The gun provides 6 spf, 60 deg ph, with modeled average pelf hole diameters of 0.42" to provide enough flow area for Crystal Seal to pass through the liner to the MBE. The liner has 2.5" x 0.125" slots (32 slots / ft) in 42' slotted joints alternating with 42' blank joints. POOH with fired gun. Verify ASF. RD CT. 3) RU 2" CTU & mixing van to blend slurry 'on- the -fly' in 2% KCI Water to be pumped down CT at steady 1.5 bpm during Crystal Seal job. RIH with large side port nozzle with no down ports. Note pipe flag to park nozzle on pelf interval at 9540 - 9545' RKB. Pump Seawater SRIT down CT at steps ramped between 1 - 2 bpm. A final steady rate we'll decide to pump Crystal Seal slurry depends on rate that can be pumped into the well at a reasonable treating pressure. Determine if the well looks OK to treat based on the SRIT. If OK to treat, continue pumping: Seawater Pad down CT at 1.5 bpm (target) until ready to swap to slurry. Maintain steady treating rate throughout treatment through Flush to monitor treating pressure at constant rate. Swap from Seawater to 2% KCI Water. Pump 2% KCI with 0.05 ppg Crystal Seal (4 mm mesh all stages) down CT. Each stage volume TBD during pumping based on treating pressure response observed during stage. Continue pumping 2% KCI w /0.10 ppg Crystal Seal (CS) down CT, or Flush if we see screen out (SO), then 2% KCI w/0.15 ppg CS down CT, or Flush if we see SO, then 2% KCI w /0.20 ppg CS down CT, or Flush if we see SO, then 2% KCI w/0.25 ppg CS down CT, or Flush should we see SO. If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of Seawater Flush to displace all Crystal Seal slurry from CT into well while POOH. If screenout 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 CT to MBE while POOH with CT to B LEM, then swap to 63 bbls of Diesel FP down CT, followed by 1 CT volume of Diesel ( -40 bbls) to FP CT and displace Diesel FP to tubing, followed by SD. RD CTU. Wait 6 hrs then return 1J-105L1 to PWI for post Crystal Seal treatment evaluation. , KUP • 1J -105 e � ConocoPhillips 0 .` Well Attributes Max Angle & MD TD Alaska. Inc. Wellborn API /UWI Field Name Well Status Inc! (°) MD (ROB) Act Btm (ftKB) rpr,ocaps 500292334600 WESTSAK INJ 92.96 9,846.46 11,735.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 32.29 4/29/2007 Well Canto -1J -105,5129 /201 2 10 25'40AM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date ----- - - - - -- - - - - -- - -- - - - Last Tag: Rev Reason: SET DIVERTER & ISO ninam 5/29/2012 HANGER, 23 _ - - - - - Casing Strings - Casing Description String 0... String ID ... Top (MOB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 30.5 3,386.8 2,253.4 45.50 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, 30108 _ WINDOW D 8 7.000 7,348.0 7,363.0 3,647.2 NIPPLE, 498 - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT, WINDOW B 8 7.000 7,707.0 7,722.0 3,703.3 2,268 I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 75/8 6.875 27.4 8,838.4 3,820.1 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ROB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE, _J r L. D - Sand Liner LEM 4 1/2 3.958 7,288.5 7,494.8 3,665.0 12.60 L - 80 IBTM 30 -3,387 Liner Details GAS LIFT, - Top Depth 6,394 (TVD) Top Ind Norni... Top (ftKB) - (ftKB) ( °) Item Description Comment ID (in) SLEEVE 1. • , - • I 7,288.5 3,638.1 83.19 PACKER L2 D - SAND LEM ZXP 5 x 7 - 5/8" Liner Top Packer TOP 4.940 6,691 _ _ 7,307.5 3,640.2 82.98 CSR L2 D - SAND LEM Casing SBR 109 C 6.26" OD x 4.75" ID 4.750 LOCATOR, 7,296 • 7,327.1 3,642.5 82.76 BUSHING L2 D - SAND LEM Reducing XO Bushing 5 Hydril 563 x 4 - 1/2" IBT 3.930 SEAL ASSY, 7.297 7,332.4 3,643.2 82.70 HANGER L2 D -SAND LEM Above Hook Hanger 3.960 7,343.3 3,644.6 82.58 HANGER L2 D -SAND LEM Inside Hook Hanger 3.688 P 7,491.5 3,664.2 77.81 SEAL ASSY L2 D -SAND LEM Baker Seal Assembly 4 -1/2" STL Box up 3.860 SLEEVE, 7,343 Casing Description String 0... String ID ... Top (ftKB) Set Depth ( /... Set De ( ND) ... String Wt... String ... String Top Thrd Whipstock D, D - Sand Liner HH 4 1/2 I 3 I 7,343 7 I 3,686.8 I 11 .60 I L - 80 BTC 7,347 WINDOW D, Liner Details 7,348 -7,363 Top Depth I I (TVD) Top Intl Nom). Top (ftKB) (ftKB) ( °) Rem Description Comment ID (in) 7,343.3 3,644.6 82.58 HANGER L2 D -SAND HOOK ASSY Baker Model B-1 Hook Hanger 75/8" x 4 1/2' 5.600 (Inside csg) o - sand Liner 7,360.0 3,646.8 82.39 HANGER L2 D -SAND HOOK ASSY Baker Model B-1 Hook Hanger 75/8" x 4 1/2" 4.000 LEM, I (D0tSide Csg) 7,288 - 7,495 7,505 3,667.3 78.19 ECP L2 D - SAND HOOK ASSY Baker Payzone External Casing Packer 3.960 Casing De scription String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B -Sand Liner LEM 14 1/2 I 3.958 I 7,464.8 7,862.5 3,725.4 I I I 12.60 I L -80 IBT D -Sand Liner H Liner Details 1 Top Depth Top loci 7,343 -7,612 2 111 (NDI Nomi... DIVERTER, Top (ftKB) (ftKB) PI Item Description Comment ID (In) 7,703 7,464.8 3,657.7 77.08 PACKER L1 B LEM ZXP 5 x 7 - 5/8" Liner Top Packer TOP 4.767 Whipstock B, 7.707 7,483.8 3,662.4 77.60 CSR L1 B LEM 109 Casing SBR 6.26" OD x 4.75 4.750 WINDOW S. 7,707 - 7.722 7,503.5 3,666.9 78.14 BUSHING L1 B-SAND LEM XO Bushing 5-1/2' Hydril 563 x 4 -1/2" IBT 3.958 7,696.5 3,699.4 81.21 HANGER L1 B -SAND LEM LEM Above Hook Hanger 3.688 7,703.3 3,700.4 81.18 HANGER L1 B-SAND LEM LEM Inside Hook Hanger 3.688 7,809.3 3,717.1 80.49 NIPPLE L1 B -SAND LEM Camco "DB -6" Nipple, I.D. 3.562 ", IBT 3.562 1 Mis 7,859.21 3,724.91 81.40ISEAL ASSY 1L1 &SAND LEM Baker Seal Assembly 4 -1/2" STL Box up 1 3.860 Casing Description String 0... String ID ... Top (IIKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd it B-Sand Liner HH 4 1/2 3.476 7,703.3 7,893.8 3,730.0 11.60 L-80 BTC B-Seed Liner 1 , Liner Details LEM, ---- Top Depth 7,465 -7,862 =MR ip ITVDI Top Inc! Noes... Top (ftKB) (ftKB) Fl Rem Description Comment ID (in) B - Send Liner 7,703.3 3,700.4 81.18 HANGER L1 B - SAND Baker Model B Hook Hanger 7 5/8" x 4 1/2' (Inside) 5.640 HH, 7,703 - 7.894 7,720.0 3,703.0 81.08 HANGER L1 B Baker Model B Hook Hanger 75/8" x 4 1/2' (Outside) 5.640 PRODUCTION, . Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 274I,e38 A -Sand Slotted Liner 4 1/2 3.476 7,820.0 11,725.0 3822.7 11.60 L -80 BTC w/ TR Liner Details Top Depth (ND) Top Inc! Nomi... Top (ftKB) (ftKB) F) Item Description Comment ID (!n) 7,820.0 3,718.8 80.68 PACKER A -SAND 5.5 "x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.500 SLOTS, 7,839.0 3,721.8 81.03 SEAL NIPPLE ' A -SAND "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.870 8,863 - 9,769 7,841.8 3,722.2 81.08 HANGER A -SAND 5.5" X 7.63" "Flex- Lock" Liner Hgr, 6.59" OD/ 4.85" ID 4.850 7,851.6 3,723.7 81.26 SBE A -SAND 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 4.750 Tubing Strings Tubing Description String 0... String ID ... Top (SOB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.992 23.0 7,323.9 3,642.1 12.60 L -80 IBT Completion Details Top Depth (ND) Top Incl Need... Top (fIKB) BM) F) Item Description Comment ID (in) 23.0 23.0 -0.04 HANGER TUBING HANGER w/ PUP 3.992 Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Sine TRO Run Stn Top (ftKB) (ftKB) F) Make Model (in) sere Type Type (in) (psi) Run Date Core... SLOTS, 1 2,267.8 1,853.7 69.17 CAMCO KBMG 1 GAS LIFT DMY BK5 0.000 0.0 6/28/2007 10,068 11.682 2 6,393.7 3,387.3 68.93 CAMCO KBMG 1 GAS LIFT DMY BEK -5 0.000 0.0 4/28/2007 A -Sand Slotted Liner, 5 7.820-it i ns TO (1 11,73 , 11,735 KUP • 1J -105 ConocoPhillips Alaska, Inc. KBGrd (ft) Rig Release Date 32.29 4/29/2007 Well Cana,. -1J -105, 5! 29!2012/0'. 25'. 40 AM 1 Schematic - Actual HANGER, 23 a-- Completion Details Top Depth (TVD) Top Inc! Nomi... { To p (ttKB) (K 497.7 ( °) Item Description Comment ID (in) E 49 8.3 497.7 7.11 NIPPLE CAMCO DB NIPPLE 3.875 CONDUCTOR, la 6,691.3 3,494.6 69.09 SLEEVE -C CMU SLIDING SLEEVE (CLOSED ON 6/29/2007) 3.812 30 - 198 7,295.5 3,638.9 83.11 LOCATOR LOCATOR 3.880 NIPPLE, 498 GAS LIFT. 7,296.6 3,639.0 83.10 SEAL ASSY GBH -22 LOCATING SEAL ASSEMBLY 3.880 2,288 or' Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth SURFACE, (TVD) Top Inc! 30 -3,357 Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 7,343 3,644.5 82.58 SLEEVE ISO SLEEVE 5/23/2012 2.500 GAS 613 4 .,. 7,347 3,645.0 82.54 Whipstock D D-SAND WHIPSTOCK 4/22/2007 SLEEVE - C, �' 7,703 3,700.4 81.18 DIVERTER 5/23/2012 2.750 ' 6.891 7,707 3,701.0 81.16 Whipstock B B -SAND WHIPSTOCK 4/9/2007 LOCATOR. 7,296 Perforations & Slots SEAL ASSY, ` Shot 7297 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh... Type Comment 1 1 8,863 9,769 3,821.1 3,816.0 WS A2, 1J - 105 4/26/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long SLEEVE. 7,343 X .125" wide Whipstock D, _ 10,068 11,682 3,809.7 3,822.4 WS A2, 1J -105 4/26/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long 7,347 x .125" wide WINDOW D. 7,348 -7,363 II Notes: General & Safety End Date Annotation 4/29/2007 NOTE: MULTI -LAT WELL - 1J -105 (A- SAND), 1J -105L1 (B-SAND), 1J -105L2 (D -SAND) 3 /2/2011 NOTE: View Schematic w/ Alaska Schematic9.0 D -Sand Liner r LEM, f 7,288-7.495 :MIL D -Sand Liner H 7 i I ,343 -7,612 12 DIVERTER, 7,703 Whipstock 9, 7,707 WINDOW B, 7.707 -7,722 I Ma Min B -Sand Liner I I r LEM. i..._.... -:l 7,465 -7.862 A ■ 13-Sand Liner HH, ( 7,703 -7.894 PRODUCTION, 278,638 SLOTS. 8.8639,789 SLOTS, 10,068 - 11,682 A -Sand Slotted Liner, 7,620- 11,725 5 TD (1J -105), 11,735 ° 2.07- 02,7 • • 2.t54% WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 1, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: SpectraFlow Log / Water Flow Log: 1J -105 Run Date: 4/29/2012 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 -105 Digital Data in DLIS format, Digital Log file, Interpretation Report 1 CD Rom 50- 029 - 23346 -00 Water Flow Log (Processed print) 1 Color Log 50- 029 - 23346 -00 SAAN1E JUN 2 0 20 SpectraFlow Log (Field print) 1 Color Log 50- 029 - 23346 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 5/1 2 Signed: 4 BaaL • • -(. I J I O' Regg, James B (DOA) pit zei v270 Sent: From: Tuesday�May, 01[ 201291@1C11 AM phillips.com] ��,� � ,1112% To: 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; Jensen, Marc D; Gauer, Jenn L Subject: RE: LPP /SSV Returned to Service 1J -105 on 04/30/2012 Jim, The low pressure pilot (LPP) on injector 1J -105 (PTD# 207 -027, 207 -028 and 207 -029) was returned to service on 04/30/2012 after the well was shut in This pilot had been defeated on 04/28/2012 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef CPF1 Production Engineer n1269conocophillips.com 659 -7493 pager 659 -7000 765 )*O , U MAY ' a 1 • • K2Gt 11- I OS Z©76270 Regg, James B (DOA) From: Regg, James B (DOA) % 1 � ' lv Sent: Tuesday, May 01, 2012 9:05 AM �` To: 'CPF1 Prod Engr' Subject: RE: LPP /SSV Defeated for 1J -105 on 04/28/2012 Careful with PTD numbers; should be 207 -027 not 207 -270 Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: CPF1 Prod Engr [ mailto :n1269©conocophillips.com] Sent: Saturday, April 28, 2012 6:29 PM To: 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; Jensen, Marc D; Gauer, Jenn L; CPF1 Prod Engr Subject: LPP /SSV Defeated for 1J -105 on 04/28/2012 Jim, 7 7-027 Ze7 -02:c5 The low pressure pilot (LPP) on injector 1J -105 (PTD# , 20,,286and 0) was defeated on 04/28/2012 when the injection pressure fell below 500 PSI once the well was put back on injection. This pressure loss is most likely due to a recent Matrix Bypass Event (MBE) between one of the laterals and 1J -103. This injector was returned to service on April 27th, 2012 after being shut in since April 05, 2011 so that an injection profile can be performed to identify the lateral involved in the MBE. As of 1700 hrs on 04/28/2012 , wellhead injection pressure is 13 psi; injection rate was 1061 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. David Lagerlef CPF1 Production Engineer n1269(a�conocophillips.com 659 -7493 pager 659 -7000 765 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 16, 2011 6:44 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 1J West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) -1 05 (207 -027 207 - 028,207 -029) 345 639 1J-118 (206 -17 ,206- 177,206 -178) 327 1020 1J-127 (206- 047,206 -048, 206 -049) 337 934 1J-154 (205- 036,205 -037) 369 623 1J-160 (207- 015,207- 016,207 -017) 352 568 1J-164 (205- 144,205 -145, 205 -146) 479 1082 1J-180 (206- 150,206 -151) 537 478 1 J -184 (206- 044,206 -045) 502 646 The AOGCC will be notified when the injection pressures have increased so as to remain above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers ` n1269 @conocophillips.com 4 Vt : :- 659 -7493 pager 659 -7000 765 9/19/2011 • • 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 -105 Run Date: 4/19/2011 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 -105 Digital Data in DLIS /LAS format, Digital Log file, Interpretation Report 1 CD Rom 50- 029 - 23346 -00 Water Flow Log 1 Color Log 50- 029 - 23346 -00 3 2.011 Injection Profile Log 1 Color Log 50- 029 - 23346 -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 L C Office: 907 - 273 -3527 Fax: 907- 273 -3535 c O i " klinton.wo 41.1.ib*pii.60W - ~; Ntif Date- 0 ' 2011 Signed: +~ _ M ''~tt' ~° ..~ ". ~ , ,~~ ~ .. a:, ~ ~,' ' ~` :;„; .:,~~" ;' C:\temp\Temporary Internet Files\OLK9\Micro6lm_Marker.doc u MEMORANDUM To: Jim Regg ~~~ (, ~ ~ ~ to P.I. Supervisor 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-lOs KUPARUK RIV U WSAK IJ-lOs Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1J-105 API Well Number: 50-029-23346-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100s16132503 Permit Number: 207-027-0 Inspection Date: s/14/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. e In ~ ~'~' Well 1J-]os "TYP .l• p T~zo7oz7o _1TypeTest sPT TVD ~ Test psI 363 A lsoo~_pA _-_1098 ]ss 1800 ~ ]s6 ]780 ~ 1780 ~ ls6 ]s6 ~ Interval axRTST p/Ii P Tubing sss 558 558 ss7 Notes: },i~;., ('~~`~~5~ 15GvPs, 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 OPERATOR: ConocoPhillips Alaska Inc. cc~~ FIELD /UNIT /PAD: Kuparuk /KRU / 1J ~~~~..~ d°~ DATE: 05/14/10 OPERATOR REP: Colee /Phillips - AES ~_ AOGCC REP: Bob Noble 9 ` `~ 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 S~ 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 MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s ~/ V • C~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 1,866 1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubin 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casin 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test V 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 ! ~3 ~~/~ r~~~ ~~~~ ( /~s ~~ ~b~53 osn vos SchNuupberger N0.5359 ~ ~;~~ ~~ w ~ . ~ Schlumberger -DCS ~~ g ~~..:.. . 2525 Gambell Street, Suite 400 AK 99503-2838 Company: IUaska Oil & Gas Cons Comm ATTN: ge~h ~--~/ ~~ ~ - ~ Attn: Christine Mahnken ~ , ~t 333 West 7th Ave, Suite 100 d~-\ k ~=~ "t' A Anchor AK 99501 ~ 7 ~ ~ ~ 1 ~ ~ Fieltl: age, ~ ~~t ~~~ ~~,~~: Kuparuk Well L Job N LOg Description ` Date BL i Colo~ CD ~ ~ 1J-105 1J-136 1E-166 1G172A ~~-~A ~ B2WY-00017 82WY•00024 62WV-00025 AXBD-00062 AP3~-00056 MEMINJECTIONPROFILE - MEMINJECTIONPHOFILE ~ MEM PRODUCTION PROFILE - MEM PRODUCTION PROFILE - SFRT - 0723/09 08/24/09 p9rz5~pg pgng~pg 09Po5/09 7 / ~ ~ 1 ~ ~ ~ ~ ~ riease slgn antl return one copy of this traosmitWl to 8eth at tbe above address or fa: to (907) 561•8317. Thank you. ~ • ~ ~.~ M~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070270 Well Name/No. KUPARUK RIV U WSAK 1J-105 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23346-00-00 MD 11735 TVD 3823 Completion Date 4/29/2007 Completion Status 1-OIL Current Status 1WINJ UIC- REQUIRED INFORMATION Mud Log No Samples No Directional Surve Ye DATA INFORMATION Types Electric or Other Logs Run: GR/Res/USIT Well Log Information: Log/ Electr Da Digital Dataset Log Log Run T Med/Frmt Number Name Scale Media No Log Cement Evaluation 5 Col 1 ~~~ Sc-~. ~~sV-t ~ lLCOg Ges-~matysis 1 Blu ,~GE~ D Las Directional Survey ~E~" D Las D/irectional Survey 'ED C Lis 15314vGamma Ray II Rp/t 15314 L/IS Verification ~D C Lis 15315r/Gamma Ray Rpt 15315 LIS Verification ~~ o Injection Profile 5 Blu "Log Injection Profile 5 Blu ~!~ED C Pds 16860 `~ection Profile ~Xog Induction/Resistivity 25 Col I __ _. (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 3000 8700 Case 4/20/2007 USCEL, USIT, GR, CCL 6- Apr-2007 50 7800 Open 6/11/2007 Gas Lift Survey w/Welltec Tractor 26-May-2007 7061 11375 Open 8/2/2007 28 7473 Open 8/2/2007 PB 1 3351 11735 Open 8/3/2007 LIS Veri, GR, ROP, FET w/Graphics 3351 11735 Open 8/3/2007 LIS Veri, GR, ROP, FET 3351 7473 Open 8/3/2007 P61 LIS Veri, GR, ROP, FET w/Graphics 3351 7473 Open 813!2007 PB1 LIS Veri, GR, ROP, FET 6350 7800 Case 12/21/2007 Injection pro, Pres, Temp, Gradio, Spin 20-Nov-2007 7142 7942 Case 9/8/2008 Mem Injection Pro, GR, CCL, Temp, Spin 19-Aug- 2008 7142 7942 Case 9/8/2008 Mem trajection Pro, GR, CCL, Temp, Spin 19-Aug- ~ ~ ~~ 2008 108 11735 ~~ 4/23/2009 MD DGR, EWR 6-Apr-2007 • ~. DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070270 Well Name/No. KUPARUK RIV U WSAK 1J-105 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23346-00-00 MD 11735 TVD 3823 Completion Date 4/29/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y ~ og _ __- -_ _ _- _ Induction/Resistivity _- 25 Col 108 ___ 3822 o --- -.~.ase 4/23/2009 _ - ----- _ _ TVD DGR, EWR 6-Apr- ~'~`T`~ 2007 ~og Induction/Resistivity 25 Col 108 7473 ~ 4/23/2009 PB1 MD DGR, EWR 6-Apr- C5 ~ ~'~ 2007 ~g Induction/Resistivity 25 Col 108 3656 ~Case~ 4/23/2009 P61 TVD DGR, EWR 6- ~ N L~ Apr-2007 '~ED C 17917~e Notes 0 0 4/23/2009 EWR and P61 in PDS, ', CGM and EMF graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? N Daily History Received? Chips Received? ~Y71~ Formation Tops ~ N Analysis Received? Comments: _. _ -- -- _ ~ ~~~J~1 v Compliance Reviewed By: _._ _ Date: w"-- • MEMORANDUM TO: Jim Regg o P.I. Supervisor ~~~ ~'~~~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IJ-105 KUPARUK RIV U WSAK IJ-105 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv 5,j ,~- Comm Well Name: KUPARUK RIV U WSAK 11-105 Insp Num: mitRCN090526111637 Rel Insp Num: API Well Number: 50-029-23346-00-00 Permit Number: 207-027-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-los Type Inj. W 'I'VD 3639 IA 1320 2000 1940 1940 P.T.D zo~oz7o TypeTest SPT Test psi zooo OA Ise ]s~ ]ss ]sa Interval 4YRTST p~ P ,/ Tubing s~9 sso ssl sso Notes: Wednesday, May 27, 2009 Page 1 of I ~~~LL LAG '1'~AI~I~l~I°°1"Ti~L ~'~~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-105+L1+L2+PB1 Apri17, 2009 AK-MW-4912996 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling , 6900 Arctic Blvd., Anchorage, AK 99518 1J-105+L1+L2+pBl 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-23346-00,60,61,70 g 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-23346-00,60,61,70 g Digital Log Images 1 CD Rom 50-029-23 346-00,60, 61, 70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 U? ~ ~d..-~ -~ 1 ~~ i "=3- ~ ~~~ t'~°i ~`~ Br<an.BUr1I1d-a~h~llt}j~yrfnn,~rnm /1x ~ ~. V ~ ~c~~--C~ ~`~1 Date: ; /, Signed: ~ ~ f~---~' o~ ~n~,s~~a t ~C/ I" ~Ri~~~F1Y61-~r1- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # r Log Description b:"~~ ~~i ~ ,s{, N0. 4861 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 09/05/08 1J-127 12096529 INJECTION PROFILE ~ - ~ ~- 08/14/08 1 1 1 R-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 1J-118 12066541 MEM INJECTION PROFILE 08/17/08 1 1 1J-122 12066542 MEM INJECTION PROFILE /(p 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE ~-[- (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE ( ~(- ~ ~p 08/19/08 1 1 iJ-105 12066543 MEM INJECTION PROFILE '}- I(D 08/19/08 1 1 2E-12 11996653 SBHP SURVEY 08/21/08 1 1 iJ-156 12080419 INJECTION PROFILE ~ 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q -/ 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ~ ` 08/22/08 1 1 2D-05 12080422 - {(p '- INJ PROF/LDL / 08/23/08 1 1 iH-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 26-03A 11996656 PRODUCTION PROFILE / 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY ~ per- l(o l 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / =- ~ $Q 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE '-- Oa L/~ 08/30/08 1 1 2E-13 12080431 SBHP SURVEY C• - G 08/31/08 1 1 2E-14 12080432 SBHP SURVEY ~-(•- 08/31/08 1 1 iB-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 1H-18 11996666 INJECTION PROFILE ~( 09/03/08 1 1 F-10 11996660 PLUG SETTING RECORD 08/28/08 1 1 iG-05 11996665 PACKER SETTING RECORD 09/02/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~a~a~7 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 1 J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1 J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 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 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 12/20/07 ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Well Job # Log Description Date BL Kuparuk Color CD 1J-105 11837540 INJECTION PROFILE r"a'1~-('~'~'~}- 11120107 1 1A-06 11837542 _ RST WFL ~t _~(G i 11/22/07 1 1Q-05 11837537 _ LDL ( 11/17/07 1 1B-12 11970607 INJECTION PROFILE T 12104107 1 2N-327 11996582 OILPHASE SAMPLER Q~- (A 12115/07 1 1D-132 11994588 SBHP SURVEY ~' - ~ 12117/07 1 3H-10B 11996580 PATCH EVALUATION 12/13/07 1 3N-02A 11970609 LDL $ - 12/05/07 1 1C-125 11964553 INJECTION PROFILE 12/01/07 1 2M-15 NIA PRODUCTION PROFILE ( (" 12110!07 1 2M-11 NIA PRODUCTION PROFILE (q ~ ( 12/08107 1 3A-03B 11970604 SCMT ''~_ ( 12/01/07 1 2T-217A 11978431 SCMT - 12/15107 1 2L-330 11837544 FULLBORE MICRO SCANNER ~ 11/27/07 1 2L-330 11837544 SONIC SCANNER 11/27107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPlSSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 0 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, lames B (DOA) Cc: CPFl DS Lead Techs; CPFl Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, iJ-164, iJ-180 Tom ;Jim, The LPP/SSV's on all of the Nest Sak DS1 E and DS1 J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also fisted. I wasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as well so I included both. WELL ID Percnlt to Dri6i No. 1E-112 204-091 (MAINBORE), 204-092 (L1), 204-093 (L2} 1J-102 206-110 (MAINBORE}, 206-111 (L1), 206-112 (L2) ~--~1J-105 207-027 (MAINBORE}, 207-028 (L1}, 207-029 (L2) 1J-127 206-047 (MAINBORE), 206-048 (L1), 206-049 (L2) 1J-160 207-015 (MAiNBORE), 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAiNBORE), 205-146 (L1), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these we{Is was sent 7f9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Bunt /Pete Nezaticky /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, inc. Phone: (907) 659-7061 Fax: (907} 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 • WELL LOG TRANSMITTAL LJ To: State of Alaska July 2, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1 J-105 PB 1 AK-MW-4912996 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23346-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchors asks 518 ~ ~ ~ ~ ~. _' ~ ~~~ ~ ~~~~ Date: Signed: :c~~,oe e ~-;~ ~~-~---vas- # r S3i5J ! • To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-105 July 2, 2007 AK-MW-4912996 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23346-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchora~, 9 :~ ~:~ ~° Date: ;~ ~~ ~~, ~ ?0~1 l~~ u Signed: 17-Jul-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-105 Dear Dear Sir/Madam: Enclosed is one disk with the'`.PTT and *.PDF files. Tie-on Survey: 7,061.58' MD Window /Kickoff Survey 7,071.00' MD (if applicable) Projected Survey: 11,375.00' 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? ~ ~0 7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • 17-Jul-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-105PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey Projected Survey: 28.00' MD 0.00' MD (if applicable) 7,473.00' 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 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ ~?-~~.~ MEIVI®RAND~JI~ • To: Jim Regg ~~~~ ~ % ~~~~~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday. July 20, 2007 SUBJECT: Mechanicai Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-lOS KUPARUK RIV U WSAK 11-lOS Src: Inspector nrnN_l,nlyFiilF.NTi A i , a,~~, 0~7 Reviewed By: P.I. Suprv~ Comm Well Name: KUPARUK RIV U WSAK iJ-105 API Well Number: 50-029-23346-00-00 Inspector Name: Bob Noble mitRCN070714190922 Insp Num: Permit Number: 207-027-0 Inspection Date: 7/14/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-105 (Type Inj. W i TVD 3635 IA 1540 T 2000 L 1980 1980 j I P.T.D. 2o~oz~o ITypeTest SPT ~ Test psi ~ zooo ; OA ~ 160 ~ 160 160 ~ 160 I ~j ~ Interval ~T~ P/F P /"~ Tubing; 6o I 60 ~ 60 60 ~ ~ j Notes: Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO ~~~ JUG -~ ~' 20~? 1. Operations Performed: Rbandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 8S , ~ to In' ~ ~5Sl Alter Casin g ^ Pull Tubing ^ Perforate New Pool ^ C rT ~n~~GC t~ Waiver ^ Time Extensio Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 207.027. ~- 3. Address: Strati ra hic g p ^ Service ~ ^ 6. APt Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23346-00 7. KB Elevation (ft): 9. Welt Name and Number:. RKB 109' ,~ 1 J-105 8. Property Designation: 10: Field/Pool(s): ,, ALD 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11735' feet true vertical 3823' '~` feet Plugs (measured) Effective Depth measured 11725 feet Junk (measured) true vertical 3823 feet Casing Length. Size MD TVD Burst .Collapse Structural CONDUCTOR 80' 20" 80' 80' SURFACE 3278' 10-3/4" 3387 2255' WINDOW L2 1' 7-5/8" 7349' 3645' WINDOW L1 1' 7-5/8" 7708' 3701' PRODUCTION 8729' 7-5/8" 8838' 3820' A-Sand Slotted liner 7820' 4-1/2" 11725' 3823' Perforation depth: Measured depth: 8863' - 11682' true vertical depth: 3821' - 3822' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7324' MD. Packers &SSSV (type & measured depth) PKR =LEM ZXP Liner top pkr, LEM ZXP Liner top pkr, HRD ZXP Liner top pkr. PKR = 7288', 7465', 7820' SSSV= NIP SSSV= 493' 12. Stimulation or cement squeeze summary: ~p~~~+ 1~64/1r1r3 BFL ~u~ 2 3 aoo, 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 838 328 28 932 202 Subsequent to operation 2014 ~` 1204 -3 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 ' Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q - WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 307-186 contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technicia n Signature *2~`~~/. ' ~l Phone 659-7535 / Date ~/ ~ / / o Form 10-404 Revised 04/2004 ~/~~ Submit Original Only. ~ ~ ~J-905 ~E~G~6~`~E®~! ®~ ~flfORE~ GQP~1~L~~~~ ~U~~A~Y 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 ~ a4''1-~a'~ 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-136 LPP defeated 06/08/2007, back in service 07/01/2007 Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 7/10/2007 A ;q ~ ~kf jS ~ f ~ ii SARAH PALIN, GOVERNOR _..• s..P ~~ OIL oast' ~]r~*7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T-SFiRQA'1'IOZ1T CO~IrIISSIOIQ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105 Sundry Number: 307-186 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~~ day of June, 2007 Encl. ~'-~~" Chairman STS 6 ~~ ~!7 ~ ~ ~, ~~$ ~13~ ~ ~.ECEIVE STATE O~ALASKA lai ALASKA OIL AND GAS CONSERVATION COMMISSION I ~~ JUN 0 5 2007 APPLICATION FOR SUNDRY APPROVAL~iaska Uil & Gas Cons. Commission 20 AAC 25.280 n.,,.t,~~~~o 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved r ram g pp p og ^ Pull Tubing ^ Perforate New Pool ^ Producer to Re-enter Suspended Well ^ Injector 2. Operator. Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development^ Exploratory ^ 207-027 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23346-00 " 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? Y@S ^ No ~ 1J-105 ` 9. Property Designation: Lf G 6f c7 ~~ 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit ~'~ ~- LSGGL ~ l.' RKB 109' Kuparuk River Field /West Sak Oil Pool °~ 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11735' -- 3823' 11725' 3823' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 80' 80' SURFACE 3278' 10-3/4" 3387' 2255' WINDOW L2 1' 7-5/8" 7349' 3645' WINDOW L1 1' 7-5/8" 7708' 3701' PRODUCTION 872g' 7-5/8" 8838' 3820' Alternating Slotted liner 7820' 4-1/2" 11725' 3823' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): sass' - 11682' 3821' -3822' 4-1 /2" L-80 7324' Packers and SSSV Type: Packers and SSSV MD (ft) PKR =LEM ZXP Liner top pkr, LEM ZXP Liner top pkr, HRD ZXP Liner top pkr PKR = 7288', 7465', 7820' SSSV=NIP SSSV= 493' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 25, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Nam Robert D. Christensen Title: Production Engineering Technician Signatur Phone 659-7535 Date Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: O~cG~O ~S ~ ~. G.CLO~~ W l ~ t ~ a...\~ Subsequent Form Required: '-1© ~ ®F~ ~uN ~ ~ ?~Q~ APPROVED BY ~~ Approved by: COMMISSIONER THE COMMISSION Date: ! Form 10-403 Revised 06/2006 Sub~it~ JJ~~~ to L~ w / /G'-/2• 7 • ConocoPhillips June 1, 2007 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 • Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk West Sak wells 1J- IOS, 1J-lOSLl, and 1J-lOSL2 from Oil Production to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 1J-lOS (PTD 207-027), 1J-IOSLI (PTD 207-028), and 1J-lOSL2 (PTD 207-029). If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 6S9-7S3S. Sincerely, Robert D. Christensen Attachments • 1J-105 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-105. This well has been pre-produced for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1 J-105 will provide pressure support for the West Sak A sands. The 10-3/4" Surface casing (3387' and 12254' tvd) was cemented with 600 sx AS Lite followed by 198 sx LiteCRETE. The 7-5/8" Intermediate casing (8838' and / 3820' tvd) was cemented with 480 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand LEM ZXP 4- 1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7288' and / 3635' tvd, Upper B sand LEM ZXP 4-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7465' and / 3662' tvd, and an Upper A sand HRD ZXP 4-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7820' and / 3719' tvd. The top of West Sak D sand was found at 7348' and / 3645' tvd. D sand Lateral window top is located @ 7348' and / 3645' tvd. The top of West Sak B sand was found at 7704' and / 3700' tvd. B sand Lateral window top is located @ 7707' and / 3701' tvd. The top of West Sak A sand was found at 7894' and / 3730' tvd. • • KRU 1J-105 ConocoPhillips Alaska, Inc. 1J-105 LOCATOR (7296-7297, OD:5.500) SBR (7307-7327, OD:6.300) W hipstcek (7347-7360, OD:6.875) Perf ;10068-11682) ~ pipe MECHANICAL INTEGRITY P.EPORT ~~~~~` BUD L'.=~ : ~ ~~a~^O~ OPER ~ FIELD ~Q~~ `~~~ ~~~ =. ~ G _ .. S ~ ., ~ . . ~ ~~~-~"1 i; I_i. NUMB ER ' ~ -' ~C7S `.._.~~ ~. LL DAT ~_ TD : ~,~~~5.?~.. ~~~3 TVD ; ?BTD : ?ID -'~ Casing: ~-t~~~ Shoe: ~s~~ MD SS~I~ TVA; LV: t~(~. ?~ 1~1~ T~`i -=:~e_ . Shoe. `~ o-le Sire ~~~~~ and TVD ; Set a t ~~~~~ P e r f s ~--v.~`~ a~ t o ~ ~J~~ ~C'r'~A?~ =C~ `. TNTEGRT'I~ - P?AT # I Anru~.us Press Test: I? ; 15 min ~0 min Comments '~*'CHANIC~~, INTEGRITY - PART # Z ~-'7Ca 2~oa-~ ~ ~~3 h~`S Cement Voles :~ Amt. Liner Csg ~9 DvS~c DV ~ I~ C,~t JoI to cover oers ~Sbb~S ~~~'1Sx~uic`\~o~C~a--wOr~j ~Sppc ~3pZokS - :eoretical TOC ~ 3pZ~,kS "~QC ~.-SQ~~ V~~~ X0.5 =~~~ ~OV~c~G~Cc s Cement Bond Log (Yes or No) \~S In AOGCC File ~~~ C3L Evaluation, gone ~oove perfs ~~~ cc tSO lc~ Production Log: Ty-pe_ ~.~~~~~ h Evaluation CONC--LJS?Ot1S Part #I: ~ar~ TZ: ~~` ~s l~ ~~~~~~ 06/08/07 ~~~~~~U~~~e~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ,~ , ~ -, ;. ~,. i ~, ~~~ . ` , a° 1, aa~-e~~ Log Description NO, 4286 Company Field: Date BL Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD ~~ 2M-13 91665442 SBHP SURVEY 05/28107 1 9J-105 11632710 GLS 05/26/07 1 2N-305 11632713 SBHP SURVEY 05129/07 1 1 R-20 11665444 LDL .05130107 1 1 Q-03 11630480 PRODUCTION PROFILE :06101107 1 3S-18 11629016 . PRODUCTION PROFILE 06103107 1 2M-02 NIA SBHP SURVEY 06104/07 1 2M-06 11628958 SBHP SURVEY 06105107 1 2M-04 11629022 SBHP SURVEY 06105107 1 1 H-11 11629026 PRODUCTION PROFILE 06/07/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ • ConocoPhillips May 21, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-105, 1 J-105L1, 1 J-105L2 Dear Commissioner: ~'~l~AE® MAY ~ 2 2007 lasa b~i(~ Cas Cans. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1 J-105, 1 J-105L1, 1 J- 105L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, 1 R. Thomas Kuparuk Drilling Team Leader CPAI Drilling . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad { a q ~k .. ~. • STATE OF ALASKA ~ MAY 2 L 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ~„~~ ail ~ ass Cons. Commis5101 WELL COMPLETION OR RECOMPLETION REPORT AND LO>O~I'~g~ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: April 29, 2007 12. Permit to Drill Number: 207-027 / ~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: March 21, 2007 13. API Number: 50-029-23346-00 4a. Location of Well (Governmental Section): Surface: 2186' FSL, 2432' FEL, Sec. 35, T11 N, R10E, UM ' 7. Date TD Reached: April 5, 2007 14. Well Name and Number: 1J-105 Top of Productive Horizon: 460' FSL, 2016' FWL, Sec. 36, T11N, R10E, UM 8. KB (ft above MSL): 109' AMSL Ground (ft MSL): 81' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2507 FNL, 2150' FWL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 11725' MD / 3823' TVD West Sak Oil Pool ,- 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 558776 ~ y- 5945998 ~ Zone- 4 10. Total Depth (MD + ND): 11735' MD / 3823' TVD 16. Property Designation: 25661, 25662 ' TPI: x- 563238 y- 5944308 Zone- 4 Total Depth: x- 563399 ' - 5941343 ~ Zone- 4 11. SSSV Depth (MD + ND): nipple @ 423' 17. Land Use Permit: 471, 2177 18. Directional Survey: Yes ^~ No^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (lVD): 1514' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res/USIT 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" 78.6# H-40 28' 108' 28' 108' 42" 36o sx AS 1 10.75" 45.5# L-80 28' 3387' 28' 2254' 13.5" 600 sx AS Lite, i 98 sx DeepCRETE 7.625" 29.7# L-80 28' 8838' 28' 3820' 9.875" 480 sx DeepCRETE 4.5" 11.6# L-80 7820' 11725' 3719' 3823' 6.75" slotted and blank liner 23. Open to production or injection? Yes /^ No if Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7324' 7820' refer to slotted liner attached ` 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production May 11, 2007 Method of Operation (Flowing, gas lift, etc.) pre-producing injector -shares production with 1J-105L1 and 1J-105L2 Date of Test 5/14/2007 Hours Tested 8 hours Production for Test Period --~ OIL-BBL 676 GAS-MCF 847 WATER-BBL 21 CHOKE SIZE 40 Bean GAS-OIL RATIO 1342 Flow Tubing press. 348 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1931 GAS-MCF 2592 WATER-BBL 62 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oii, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071-. not applicable s VfRiFi€~ ~t:~ Form 10-407 Revised 2/2007 oRic~NH~ CONTINUED ON REVERSE SIDE 1~8t~MS BI`L ~u~ o ~ X007 /SD s• zs :°7 ~ ~~7 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface brieFly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1651' 1514' needed, and submit detailed test information per 20 AAC 25.071. T3 3387' 2255' K15 3387' 2255' Ugnu C 5426' 3020' Ugnu B 5935' 3210' Ugnu A 6142' 3290' K13 6764' 3519' West Sak D 7348' 3645' West Sak C 7557' 3677' West Sak B 7704' 3700' West Sak A4 7gg4' 3730' fJ/A West Sak A3 8094' 3758' West Sak A2 8758' 3817' 1J-105P61 TD 7473' 3657' - Formation at total depth: Kuparuk A2 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 Thomas Title: Drilling Team Leader ~~ J ~ r (~ 7 ~ Signature ____ one Date z~s 6~3 INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhofe well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report __ __ __ Ceoipany: ConocoPhillips Alaska Inc. llate: 5/17/2007 -time: 1G:3~:1~ Page: 1 Field: Kuparuk River Unit Co-ordinate(NE)Reference: We€I:'1J-105, True North - Site: Kuparuk 1J Pad Vertical (T'~'Di Reference: 1J-fi05 : 109.0 Well: 1J-'105 Section (~~) Kcference: Well'(O.OON,O.OOE,180.OOAzi) ~Yellps~th: 1 J-105 Survey (alcula~iun ~tcthod: Minimum Curvature - Ilh: 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-105 Slot Name: Well Position: +N/-S 79.11 ft Northing: 5945998.64 ft Latitude: 70 15 47.036 N +E/-W -13.17 ft Easting : 558776.16 ft Longitude: 149 31 29.390 W Position Uncertainty: 0.00 ft Wellpath: 1J-105 Drilled From: 1J-105P61 500292334600 Tie-on Depth: 7061.58 ft Current Datum: 1 J-105: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/18/2007 Declination: 23.58 deg Field Strength: 57620 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 I~Survey Program for Definitive Wellpath Date: 5/17/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 50.00 826.00 iJ-105PB1 gyro (50.00-826.00) CB-GYRO-SS Camera based gyro single shot 857.82 7061.58 1J-105PB1 (857.82-7347.33) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7071.00 11695.87 1J-105 (7071.00-11695.87) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ___- --__ i11D Incl Azim ~lyl) Sys~CVll N/S E/W i~iapiti ititapE foul ft deg deg ft ft ft ft ft ft 28 .00 0.00 0. 00 28.00 -81.00 0. 00 0. 00 5945998. 64 - 558776. 16 ~ TIE LINE 50. 00 0.16 53. 62 50.00 -59.00 0. 02 0. 02 5945998. 66 558776. 18 CB-GYRO-SS 100. 00 0.30 141. 62 100.00 -9.00 -0. 04 0. 16 5945998. 60 558776. 32 CB-GYRO-SS 171. 00 0.36 41. 63 171.00 62.00 -0. 02 0. 43 5945998. 62 558776. 59 CB-GYRO-SS 264. 00 0.56 58. 53 264.00 155.00 0. 43 1. 01 5945999. 08 558777. 16 CB-GYRO-SS ~ I! 354. 00 2.43 40. 52 353.96 244.96 2. 11 2. 62 5946000. 77 558778. 77 CB-GYRO-SS 445. 00 5.63 40. 67 444.72 335.72 6. 97 6. 79 5946005. 66 558782. 89 CB-GYRO-SS 537 .00 8.19 47. 34 536.05 427.05 14. 83 14. 55 5946013. 58 558790. 59 CB-GYRO-SS 629 .00 10.54 48. 84 626.82 517.82 24. 81 25. 70 5946023. 65 558801. 67 CB-GYRO-SS 656 .00 11.03 48. 60 653.34 544.34 28. 15 29. 50 5946027. 01 558805. 44 CB-GYRO-SS 731 .00 13.44 44. 36 726.63 617.63 39. 12 40. 98 5946038. 08 558816. 83 CB-GYRO-SS 826 .00 17.70 47. 21 818.13 709.13 56. 84 59. 30 5946055. 93 558835. 01 CB-GYRO-SS ~ 857. 82 17.28 47. 55 848.48 739.48 63. 31 66. 34 5946062. 46 558842. 00 MWD+IFR-AK-CAZ-SC 954. 15 20.32 51. 42 939.66 830.66 83. 40 89. 98 5946082. 74 558865. 48 MWD+IFR-AK-CAZ-SC ': 992. 72 21.50 53. 16 975.69 866.69 91. 82 100. 87 5946091. 23 558876. 30 MWD+IFR-AK-CAZ-SC 1049. 19 23.94 55. 41 1027.77 918.77 104. 53 118. 59 5946104. 08 558893. 92 MWD+IFR-AK-CAZ-SC 1143. 69 27.32 56. 79 1112.97 1003.97 127. 30 152. 53 5946127. 11 558927. 67 MWD+IFR-AK-CAZ-SC 1183. 40 27.88 56. 24 1148.16 1039.16 137. 45 167. 87 5946137. 38 558942. 93 MWD+IFR-AK-CAZ-SC 1239. 22 29.39 56. 68 1197.15 1088.15 152. 23 190. 17 5946152. 33 558965. 11 MWD+IFR-AK-CAZ-SC j 1282 .82 30.20 56. 72 1234.98 1125.98 164. 12 208. 27 5946164. 37 558983. 13 MWD+IFR-AK-CAZ-SC i 1378 .63 36.29 57. 82 1315.08 1206.08 192. 47 252. 46 5946193. 06 559027. 08 MWD+IFR-AK-CAZ-SC 1429 .96 38.83 58. 54 1355.76 1246.76 208. 96 279. 05 5946209. 75 559053. 54 MWD+IFR-AK-CAZ-SC 1478 .00 40.28 57. 98 1392.80 1283.80 225. 06 305. 06 5946226. 05 559079. 43 MWD+IFR-AK-CAZ-SC ~ 1525. 94 40.22 57. 52 1429.39 1320.39 241. 59 331. 26 5946242. 78 559105. 49 MWD+IFR-AK-CAZ-SC 1582. 89 42.42 56. 42 1472.16 1363.16 262. 09 362. 78 5946263. 53 559136. 84 MWD+IFR-AK-CAZ-SC 1620. 06 44.49 55. 67 1499.14 1390.14 276. 37 383. 98 5946277. 97 559157. 93 MWD+IFR-AK-CAZ-SC 1669. 60 46.18 55. 43 1533.96 1424.96 296. 30 413. 03 5946298. 13 559186. 83 MWD+IFR-AK-CAZ-SC j 1715.45 48.80 55. 59 1564.94 1455.94 315. 44 440. 89 5946317. 48 559214. 53 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. 1}ate: 511 712 00 7 'Cime: 10:3E3:18 f'a~!e: 3 Field: Kuparuk River Unit Co-or dinate(NE} Reference: Well: 1J-10 5, True North Site: Ku paruk 1J Pad Vertical (T1~ D) Reference: 1 J-105-: '10 9.0 Well: 1J -105 Section (VS) Reference: Well (O:OON ,O.O OE,180.OOAzi) Wellpath: 1J -105 Surve y Calc ulationDlethod: MinimumC urva ture Db: Oracle Sung _ - 11D lucl ~zim 7'11) ~S~s l ~"D ?tS EJW MapN A1ap11; Tool ft deg deg, ft ft ft ft ft ft 1756.82 51.18 55.32 1591. 54 1482.54 333. 40 466. 98 5946335. 65 559240. 48 MWD+IFR-AK-CAZ-SC 1809.45 51.26 56.92 1624. 50 1515.50 356. 27 501. 04 5946358. 78 559274. 36 MWD+IFR-AK-CAZ-SC 1877.54 54.55 57.79 1665. 57 1556.57 385. 56 546. 77 5946388. 42 559319. 85 MWD+IFR-AK-CAZ-SC 1904.90 56.10 57.96 1681. 13 1572.13 397. 52 565. 83 5946400. 53 559338. 81 MWD+IFR-AK-CAZ-SC ~ 1955.07 55.90 57.63 1709. 19 1600.19 419. 69 601. 02 5946422. 97 559373. 83 MWD+IFR-AK-CAZ-SC ~ 2000.46 57.26 56.55 1734. 19 1625.19 440. 28 632. 82 5946443. 80 559405. 47 MWD+IFR-AK-CAZ-SC ! 2035.72 58.97 55.94 1752. 81 1643.81 456. 91 657. 72 5946460. 63 559430. 23 MWD+IFR-AK-CAZ-SC 2094.86 62.29 57.36 1781. 81 1672.81 485. 23 700. 77 5946489. 28 559473. 05 MWD+IFR-AK-CAZ-SC 2160.94 64.27 57.76 1811. 52 1702.52 516. 89 750. 58 5946521. 32 559522. 61 MWD+IFR-AK-CAZ-SC 2190.98 65.61 58.31 1824. 25 1715.25 531. 29 773. 66 5946535. 91 559545. 58 MWD+IFR-AK-CAZ-SC i 2255.80 68.74 56.23 1849. 39 1740.39 563. 60 823. 90 5946568. 60 559595. 56 MWD+IFR-AK-CAZ-SC 2284.90 69.79 56.29 1859. 69 1750.69 578. 72 846. 54 5946583. 89 559618. 07 MWD+IFR-AK-CAZ-SC 2329.52 69.74 56.72 1875. 13 1766.13 601. 82 881. 45 5946607. 27 559652. 80 MWD+IFR-AK-CAZ-SC 2379.75 69.84 56.48 1892. 48 1783.48 627. 77 920. 80 5946633. 52 559691. 94 MWD+iFR-AK-CAZ-SC 2427.93 69.71 53.78 1909. 14 1800.14 653. 61 957. 89 5946659. 65 559728. 83 MWD+IFR-AK-CAZ-SC 2475.69 69.43 53.96 1925. 81 1816.81 680. 00 994. 04 5946686. 31 559764. 76 MWD+IFR-AK-CAZ-SC 2573.07 69.07 55.90 1960. 31 1851.31 732. 32 1068. 56 5946739. 21 559838. 87 MWD+IFR-AK-CAZ-SC 2668.62 69.00 55.97 1994. 50 1885.50 782. 30 1142. 48 5946789. 76 559912. 39 MWD+IFR-AK-CAZ-SC 2761.03 69.27 56.63 2027. 41 1918.41 830. 21 1214. 32 5946838. 22 559983. 84 MWD+IFR-AK-CAZ-SC 2857.69 69.10 57.13 2061. 76 1952.76 879. 58 1289. 99 5946888. 18 560059. 12 MWD+IFR-AK-CAZ-SC 2951.99 70.36 58.28 2094. 43 1985.43 926. 84 1364. 76 5946936. 01 560133. 51 MWD+IFR-AK-CAZ-SC I 3047.78 68.99 55.48 2127. 71 2018.71 975. 90 1439. 99 5946985. 66 560208. 35 MWD+IFR-AK-CAZ-SC ' 3141.74 67.32 56.57 2162. 67 2053.67 1024. 64 1512. 31 5947034. 95 560280. 28 MWD+IFR-AK-CAZ-SC I 3237.01 67.55 56.57 2199. 23 2090.23 1073. 11 1585. 73 5947083. 99 560353. 31 MWD+IFR-AK-CAZ-SC 3345.45 69.14 58.63 2239. 25 2130.25 1127. 10 1670. 82 5947138 .64 560437. 97 MWD+IFR-AK-CAZ-SC 3442.21 65.71 59.55 2276. 39 2167.39 1172. 99 1747. 46 5947185 .13 560514. 24 MWD+IFR-AK-CAZ-SC 3537.73 65.96 61.45 2315. 49 2206.49 1215. 90 1823. 31 5947228 .62 560589 .75 MWD+IFR-AK-CAZ-SC 3596.12 65.22 64.10 2339. 63 2230.63 1240. 23 1870. 58 5947253 .31 560636 .82 MWD+IFR-AK-CAZ-SC 3633.41 65.88 65.30 2355. 06 2246.06 1254. 74 1901. 27 5947268. 06 560667. 40 MWD+IFR-AK-CAZ-SC 3669.03 67.11 65.93 2369. 27 2260.27 1268. 22 1931. 02 5947281. 77 560697. 04 MWD+IFR-AK-CAZ-SC 3728.04 67.16 66.18 2392. 20 2283.20 1290. 29 1980. 71 5947304. 22 560746. 55 MWD+IFR-AK-CAZ-SC 3777.68 67.17 68.01 2411. 46 2302.46 1308. 09 2022. 85 5947322. 36 560788. 55 MWD+IFR-AK-CAZ-SC I 3825.12 68.49 69.59 2429. 37 2320.37 1323. 98 2063. 81 5947338 .56 560829. 38 MWD+IFR-AK-CAZ-SC ~ I 3918.86 68.09 74.35 2464. 06 2355.06 1350. 93 2146. 59 5947366 .15 560911. 94 MWD+IFR-AK-CAZ-SC 4014.42 67.11 75.39 2500. 47 2391.47 1373. 99 2231. 88 5947389 .88 560997 .03 MWD+IFR-AK-CAZ-SC 4110.62 67.51 80.06 2537. 60 2428.60 1392. 85 2318. 57 5947409 .41 561083 .57 MWD+IFR-AK-CAZ-SC 4205.78 68.38 84.20 2573. 35 2464.35 1404. 91 2405. 91 5947422 .15 561170 .80 MWD+IFR-AK-CAZ-SC 4300.80 67.45 87.10 2609. 08 2500.08 1411. 59 2493. 70 5947429 .52 561258 .52 MWD+IFR-AK-CAZ-SC ~ 4395.43 68.23 92.41 2644. 79 2535.79 1411. 96 2581. 29 5947430 .57 561346 .11 MWD+IFR-AK-CAZ-SC i 4493.63 67.18 94.70 2682. 05 2573.05 1406. 33 2671. 97 5947425 .65 561436 .81 MWD+IFR-AK-CAZ-SC 4588.36 68.50 96.34 2717. 78 2608.78 1397. 89 2759. 29 5947417 .89 561524 .19 MWD+IFR-AK-CAZ-SC 4683.41 I 67.55 95.81 2753. 35 2644.35 1388. 56 2846. 94 5947409 .24 561611 .90 MWD+IFR-AK-CAZ-SC 4779.17 68.30 99.82 2789. 35 2680.35 1376 .49 2934. 83 5947397 .86 561699 .87 MWD+IFR-AK-CAZ-SC 4872.63 69.50 104.99 2823. 02 2714.02 1357. 75 3019. 94 5947379 .79 561785 .12 MWD+tFft-AK-CAZ-SC 4968.32 69.06 108.17 2856. 88 2747.88 1332. 22 3105. 71 5947354 .93 561871 .08 MWD+IFR-AK-CAZ-SC 5065.43 69.07 110.92 2891. 58 2782.58 1301. 88 3191. 17 5947325 .26 561956 .77 MWD+IFR-AK-CAZ-SC !, 5159.58 69.81 114.32 2924. 66 2815.66 1267. 97 3272. 53 5947291 .99 562038 .38 MWD+IFR-AK-CAZ-SC 5255.69 69.23 114.40 2958. 28 2849.28 1230 .84 3354. 55 5947255 .50 562120 .68 MWD+IFR-AK-CAZ-SC 5349.24 68.78 115.10 2991 .80 2882.80 1194 .27 3433. 86 5947219 .56 562200 .27 MWD+IFR-AK-CAZ-SC 5444.91 68.27 118.24 3026 .83 2917.83 1154 .32 3513. 41 5947180 .24 562280 .11 MWD+IFR-AK-CAZ-SC ~ 5539.50 68.35 121.32 3061 .80 2952.80 1110 .67 3589. 68 5947137 .19 562356 .72 MWD+IFR-AK-CAZ-SC i 5634.92 I 68.64 124.68 3096 .79 2987.79 1062 .33 3664. 12 5947089 .43 562431 .53 MWD+IFR-AK-CAZ-SC I Halliburton Company Survey Report Company: ConocoPhillips Alaska !nc Date: 5f17/2007 Time:. 10:38:13 P:~~c: 3 Field: Kuparuk River Unit Co-ordinate(NE)Reference: Wekl:1J-105, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: ~J-105.: 109.0 Wetl: 1J-105 Section (VS) Reference:. Well (0'OON,O.OOE,180.OOAzi) Wellpath: iJ-105 Survey Calculation Alethod: Minimum Curvature Uh: (Jracle Survev MD Lml .1~im TVD Sys TVD N/S E/~V MzipN MapE ~ ~ ~~~Tool ft deg deg ft ft ft ft ft ft 5729.60 67.81 128.24 3131.92 3022.92 1010.10 3734.83 5947037.76 562502.63 MWD+IFR-AK-CAZ-SC ~ 5821.68 68.00 131.77 3166.56 3057.56 955.26 3800.16 5946983.44 562568.39 MWD+IFR-AK-CAZ-SC 5917.84 67.17 133.65 3203.23 3094.23 894.97 3865.48 5946923.67 562634.17 MWD+IFR-AK-CAZ-SC 6013.13 67.29 136.78 3240.12 3131.12 832.62 3927.37 5946861.81 562696.53 MWD+IFR-AK-CAZ-SC ~I 6107.84 66.97 139.97 3276.94 3167.94 767.40 3985.33 5946797.05 562754.99 MWD+IFR-AK-CAZ-SC II 6204.07 66.40 144.53 3315.04 3206.04 697.55 4039.42 5946727.63 562809.62 MWD+IFR-AK-CAZ-SC 6298.64 67.96 148.24 3351.73 3242.73 624.97 4087.65 5946655.44 562858.41 MWD+IFR-AK-CAZ-SC 6392.55 68.51 151.67 3386.56 3277.56 549.49 4131.30 5946580.30 562902.65 MWD+IFR-AK-CAZ-SC 6487.79 68.90 155.54 3421.16 3312.16 470.02 4170.74 5946501.15 562942.70 MWD+IFR-AK-CAZ-SC 6583.62 68.87 159.34 3455.69 3346.69 387.48 4205.03 5946418.90 562977.63 MWD+IFR-AK-CAZ-SC 6680.00 68.68 161.33 3490.59 3381.59 302.89 4235.26 5946334.55 563008.52 MWD+IFR-AK-CAZ-SC 6775.36 72.18 163.40 3522.53 3413.53 217.27 4262.46 5946249.15 563036.38 MWD+IFR-AK-CAZ-SC 6870.19 76.19 165.88 3548.37 3439.37 129.31 4286.60 5946161.39 563061.21 MWD+IFR-AK-CAZ-SC I 6965.40 76.34 167.67 3570.98 3461.98 39.28 4307.76 5946071.54 563083.06 MWD+IFR-AK-CAZ-SC 7061.58 78.85 169.66 3591.64 3482.64 -52.81 4326.21 5945979.60 563102.23 MWD+IFR-AK-CAZ-SC i 7071.00 79.11 168.78 3593.44 3484.44 -61.89 4327.94 5945970.53 563104.03 MWD+IFR-AK-CAZ-SC 7110.68 79.31 169.89 3600.87 3491.87 -100.20 4335.15 5945932.29 563111.54 MWD+IFR-AK-CAZ-SC 7159.39 79.06 171.55 3610.01 3501.01 -147.42 4342.87 5945885.14 563119.63 MWD+IFR-AK-CAZ-SC 7209.25 78.47 171.25 3619.72 3510.72 -195.77 4350.18 5945836.85 563127.32 MWD+IFR-AK-CAZ-SC 7252.45 77.54 170.59 3628.70 3519.70 -237.50 4356.85 5945795.18 563134.31 MWD+IFR-AK-CAZ-SC ~ 7346.78 82.54 171.74 3645.01 3536.01 -329.27 4371.10 5945703.53 563149.28 MWD+IFR-AK-CAZ-SC ~! 7395.05 82.00 171.17 3651.51 3542.51 -376.57 4378.21 5945656.29 563156.76 MWD+IFR-AK-CAZ-SC 7443.98 81.97 172.22 3658.33 3549.33 -424.52 4385.21 5945608.41 563164.13 MWD+IFR-AK-CAZ-SC 7534.08 78.98 175.26 3673.24 3564.24 -512.82 4394.91 5945520.19 563174.51 MWD+IFR-AK-CAZ-SC 7629.17 81.59 176.34 3689.28 3580.28 -606.29 4401.77 5945426.79 563182.10 MWD+IFR-AK-CAZ-SC !~ 7724.22 81.06 176.52 3703.62 3594.62 -700.07 4407.62 5945333.06 563188.68 MWD+IFR-AK-CAZ-SC 7819.73 80.68 177.38 3718.78 3609.78 -794.23 4412.64 5945238.95 563194.44 MWD+IFR-AK-CAZ-SC 7867.14 81.54 177.46 3726.10 3617.10 -841.03 4414.74 5945192.18 563196.91 MWD+IFR-AK-CAZ-SC 7915.68 81.72 177.30 3733.17 3624.17 -889.00 4416.94 5945144.23 563199.48 MWD+IFR-AK-CAZ-SC 8010.24 82.42 176.53 3746.21 3637.21 -982.52 4421.98 5945050.76 563205.25 MWD+IFR-AK-CAZ-SC ~ 8106.30 81.97 177.33 3759.26 3650.26 -1077.55 4427.08 5944955.78 563211.09 MWD+IFR-AK-CAZ-SC I 8201.22 81.06 179.22 3773.27 3664.27 -1171.38 4429.91 5944861.98 563214.65 MWD+IFR-AK-CAZ-SC 8297.86 82.22 178.62 3787.32 3678.32 -1266.98 4431.71 5944766.42 563217.20 MWD+IFR-AK-CAZ-SC 8391.39 82.71 178.13 3799.58 3690.58 -1359.66 4434.34 5944673.76 563220.55 MWD+IFR-AK-CAZ-SC 8487.72 87.45 177.97 3807.84 3698.84 -1455.55 4437.60 5944577.91 563224.56 MWD+IFR-AK-CAZ-SC i 8536.50 87.36 177.71 3810.05 3701.05 -1504.25 4439.44 5944529.23 563226.78 MWD+IFR-AK-CAZ-SC 8582.48 88.17 177.60 3811.84 3702.84 -1550.15 4441.32 5944483.35 563229.02 MWD+IFR-AK-CAZ-SC 8631.65 88.03 177.69 3813.47 3704.47 -1599.26 4443.34 5944434.27 563231.42 MWD+IFR-AK-CAZ-SC 8679.40 88.36 178.32 3814.98 3705.98 -1646.95 4445.00 5944386.59 563233.45 MWD+IFR-AK-CAZ-SC 8727.29 89.33 177.35 3815.94 3706.94 -1694.80 4446.81 5944338.77 563235.64 MWD+IFR-AK-CAZ-SC 8773.79 87.11 176.28 3817.39 3708.39 -1741.20 4449.39 5944292.39 563238.58 MWD+IFR-AK-CAZ-SC 8802.53 87.42 176.33 3818.76 3709.76 -1769.85 4451.24 5944263.76 563240.65 MWD+IFR-AK-CAZ-SC 8865.87 88.08 177.12 3821.25 3712.25 -1833.03 4454.86 5944200.61 563244.76 MWD+IFR-AK-CAZ-SC 8913.91 89.01 177.71 3822.46 3713.46 -1881.01 4457.02 5944152.66 563247.30 MWD+IFR-AK-CAZ-SC 9008.21 91.05 181.49 3822.42 3713.42 -1975.29 4457.68 5944058.40 563248.69 MWD+IFR-AK-CAZ-SC 9101.13 91.91 184.15 3820.02 3711.02 -2068.05 4453.11 5943965.61 563244.85 MWD+IFR-AK-CAZ-SC 9192.98 91.91 184.85 3816.95 3707.95 -2159.57 4445.91 5943874.05 563238.36 MWD+IFR-AK-CAZ-SC 9286.69 89.50 182.72 3815.80 3706.80 -2253.05 4439.73 5943780.52 563232.91 MWD+IFR-AK-CAZ-SC 9380.12 90.37 182.83 3815.91 3706.91 -2346.37 4435.20 5943687.18 563229.11 MWD+IFR-AK-CAZ-SC 9473.76 89.26 181.64 3816.21 3707.21 -2439.94 4431.55 5943593.60 563226.19 MWD+IFR-AK-CAZ-SC 9567.66 90.06 182.80 3816.77 3707.77 -2533.76 4427.91 5943499.76 563223.29 MWD+IFR-AK-CAZ-SC 9617.91 90.37 183.68 3816.58 3707.58 -2583.93 4425.07 5943449.57 563220.84 MWD+IFR-AK-CAZ-SC 9660.08 90.31 184.10 3816.33 3707.33 -2626.01 4422.21 5943407.48 563218.31 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company:. .ConocoPhillipsAlaskalnc. llate: 5/17/2007 Time: 10:38:18 Pale: 4 Field: Kuparuk River Unit Co-ardinate(.~`E}Refercncr: We!!: 1J-105, True North Site: Kuparuk 1J Pad Vertical (TVD)Reference: 1J-105:=109.0 Welt: 1J-105 Section (VS) Reference.' Well (O.OON,O.OOE,180.OOAzi) Wellpath; 1J-105 .Survey Calculation Methott: Minimum Curvature I)h: Oracle Survey _. - MD Incl 4zim TVD Sts T4'D ft deg deg ft ft 9752.33 92.84 184.04 3813.79 3704.79 9846.46 92.96 181.16 3809.03 3700.03 9940.65 90.30 176.33 3806.35 3697.35 10034.49 86.97 174.22 3808.58 3699.58 10127.66 89.94 174.08 3811.10 3702.10 10222.26 90.43. 172.90 3810.79 3701.79 10315.13 90.12 173.47 3810.34 3701.34 '~ 10408.63 90.06 172.86 3810.20 3701.20 I, 10501.85 89.69 174.29 3810.40 3701.40 10594.83 90.30 175.76 3810.41 3701.41 10686.49 88.76 173.00 3811.16 3702.16 10783.03 89.75 172.50 3812.42 3703.42 10875.36 90.37 172.80 3812.32 3703.32 10968.27 90.00 172.47 3812.02 3703.02 ~ 11059.22 88.14 173.97 3813.50 3704.50 11149.46 88.08 174.94 3816.47 3707.47 11239.93 89.07 175.91 3818.72 3709.72 11330.96 90.06 176.01 3819.41 3710,41 11423.12 89.87 175.93 3819.47 3710.47 11512.45 89.32 175.79 3820.10 3711.10 11605.03 89.01 176.00 3821.45 3712.45 11695.87 89.63 177.78 3822.53 3713.53 ~ / 11735.00 89.63 177.78 3822.78 ~ 3713.78 N/S ---- EI~V 11apA MapE Tool ft ft ft ft - -- -2717. - _ _ 98 4415 .67 _ 5943315 - .47 563212. 48 MWD+IFR-AK-CAZ-SC -2811. 88 4411 .40 5943221. 55 563208. 95 MWD+IFR-AK-CAZ-SC -2905. 98 4413 .47 5943127. 48 563211. 75 MWD+IFR-AK-CAZ-SC -2999. 45 4421 .19 5943034. 08 563220 .20 MWD+IFR-AK-CAZ-SC -3092. 09 4430 .68 5942941. 52 563230. 42 MWD+IFR-AK-CAZ-SC -3186. 08 4441 .41 5942847. 63 563241. 88 MWD+IFR-AK-CAZ-SC -3278. 29 4452 .43 5942755. 52 563253. 61 MWD+IFR-AK-CAZ-SC -3371. 13 4463 .56 5942662. 78 563265. 47 MWD+IFR-AK-CAZ-SC -3463. 76 4473 .99 5942570. 24 563276. 62 MWD+IFR-AK-CAZ-SC -3556. 39 4482 .05 5942477. 69 563285. 40 MWD+IFR-AK-CAZ-SC -3647. 59 4491 .03 5942386. 57 563295. 09 MWD+IFR-AK-CAZ-SC -3743. 35 4503 .21 5942290. 91 563308. 02 MWD+IFR-AK-CAZ-SC -3834. 92 4515 .02 5942199. 45 563320. 54 MWD+IFR-AK-CAZ-SC -3927. 06 4526 .93 5942107. 41 563333. 17 MWD+IFR-AK-CAZ-SC -4017. 36 4537 .67 5942017. 21 563344. 61 MWD+IFR-AK-CAZ-SC -4107. 13 4546 .38 5941927. 52 563354. 02 MWD+IFR-AK-CAZ-SC x}197. 28 4553 .59 5941837. 44 563361. 94 MWD+IFR-AK-CAZ-SC -4288. 08 4560 .01 5941746. 70 563369. 06 MWD+IFR-AK-CAZ-SC -4380. 01 4566 .48 5941654. 83 563376. 25 MWD+IFR-AK-CAZ-SC -4469. 10 4572 .93 5941565. 79 563383. 40 MWD+IFR-AK-CAZ-SC -4561. 44 4579 .56 5941473. 53 563390. 74 MWD+IFR-AK-CAZ-SC -4652. 13 4584 .49 5941382. 88 563396. 38 MWD+IFR-AK-CAZ-SC -4691. 23 4586 .00 5941343. 80 ~ 563398. 20 ~ PROJECTED to TD Halliburton Company Survey Report - Company: ConacoPhillips Alaska dnc -- . - -_ Date: 5;1 ?/2007 Time: 10:23:43 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1 J-105, Tr ue North Sitc: Kuparuk 1J Pad Ve rtical (TVD)Re ference: 1J-105PB1: 109.0 WeB: 1J-105 Section(VS)Reference: WeA_(O.OON,O.OOE,180.OOAzi) R'ellpath: 1 J-105PB1 Su rve}~Calculation Method: Minimum Curva ture Db: uracle 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: 1J-105 Slot Name: ~~ Well Position: +N/-S 79.11 ft Northing: 5945998.64 ft Latitude: 70 15 47.036 N i +E/-W -13.17 ft Easti ng : 558776.16 ft Longitude: 149 31 29.390 W j Position Uncertainty: 0.00 ft ~ Wellpath: 1J-105PB1 Drilled From: Well Ref. Point ' 500292334670 Tie-on Depth: 28.00 ft i Current Datum: 1J-105P61: Height 109.00 ft Above System Datum: Mean Sea Level ~I Magnetic Data: 3/18/2007 Declination: 23.58 deg j Field Strength: 57620 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ' ft - ft -.-_ -- ft deg _ ~ 28.00 0.00 0.00 180.00 i Survey Program for Definitive Wellpath Date: 4/3/2007 Validated: No V ersion: 1 Actual From To Survey Toolcode Tool Name ft ft r 50.00 826.00 1J-105P61 gyro (50 .00-826.00) C B-GYRO-SS Camera based gyro single shot ~ 857.82 7347.33 1J-105P61 (857.82-7347.33) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC I C ~ Survey NfD Incl Azim TVD Sys TVD NlS E/W MapN b1apE Tool ft .deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945998.64 558776.16 TIE LINE i 50.00 0.16 53.62 50.00 -59.00 0.02 0.02 5945998.66 558776.18 CB-GYRO-SS 100.00 0.30 141.62 100.00 -9.00 -0.04 0.16 5945998.60 558776.32 CB-GYRO-SS ~I 171.00 0.36 41.63 171.00 62.00 -0.02 0.43 5945998.62 558776.59 CB-GYRO-SS ~ 264.00 0.56 58.53 264.00 155.00 0.43 1.01 5945999.08 558777.16 CB-GYRO-SS 354.00 2.43 40.52 353.96 244.96 2.11 2.62 5946000.77 558778.77 CB-GYRO-SS 445.00 5.63 40.67 444.72 335.72 6.97 6.79 5946005.66 558782.89 CB-GYRO-SS ~i 537.00 8.19 47.34 536.05 427.05 14.83 14.55 5946013.58 558790.59 CB-GYRO-SS 629.00 10.54 48.84 626.82 517.82 24.81 25.70 5946023.65 558801.67 CB-GYRO-SS j 656.00 11.03 48.60 653.34 544.34 28.15 29.50 5946027.01 558805.44 CB-GYRO-SS 731.00 13.44 44.36 726.63 617.63 39.12 40.98 5946038.08 558816.83 CB-GYRO-SS 826.00 17.70 47.21 818.13 709.13 56.84 59.30 5946055.93 558835.01 CB-GYRO-SS 857.82 17.28 47.55 848.48 739.48 63.31 66.34 5946062.46 558842.00 MWD+IFR-AK-CAZ-SC 954.15 20.32 51.42 939.66 830.66 83.40 89.98 5946082.74 558865.48 MWD+IFR-AK-CAZ-SC 992.72 21.50 53.16 975.69 866.69 91.82 100.87 5946091.23 558876.30 MWD+IFR-AK-CAZ-SC 1049.19 23.94 55.41 1027.77 918.77 104.53 118.59 5946104.08 558893.92 MWD+IFR-AK-CAZ-SC 1143.69 27.32 56.79 1112.97 1003.97 127.30 152.53 5946127.11 558927.67 MWD+IFR-AK-CAZ-SC 1183.40 27.88 56.24 1148.16 1039.16 137.45 167.87 5946137.38 558942.93 MWD+IFR-AK-CAZ-SC 1239.22 29.39 56.68 1197.15 1088.15 152.23 190.17 5946152.33 558965.11 MWD+IFR-AK-CAZ-SC ~ 1282.82 30.20 56.72 1234.98 1125.98 164.12 208.27 5946164.37 558983.13 MWD+IFR-AK-CAZ-SC 1378.63 36.29 57.82 1315.08 1206.08 192.47 252.46 5946193.06 559027.08 MWD+IFR-AK-CAZ-SC 1429.96 38.83 58.54 1355.76 1246.76 208.96 279.05 5946209.75 559053.54 MWD+IFR-AK-CAZ-SC 1478.00 40.28 57.98 1392.80 1283.80 225.06 305.06 5946226.05 559079.43 MWD+IFR-AK-CAZ-SC 1525.94 40.22 57.52 1429.39 1320.39 241.59 331.26 5946242.78 559105.49 MWD+IFR-AK-CAZ-SC 1582.89 42.42 56.42 1472.16 1363.16 262.09 362.78 5946263.53 559136.84 MWD+IFR-AK-CAZ-SC 1620.06 44.49 55.67 1499.14 1390.14 276.37 383.98 5946277.97 559157.93 MWD+IFR-AK-CAZ-SC 1669.60 46.18 55.43 1533.96 1424.96 296.30 413.03 5946298.13 559186.83 MWD+IFR-AK-CAZ-SC 1715.45 48.80 55.59 1564.94 1455.94 315.44 440.89 5946317.48 559214.53 MWD+IFR-AK-CAZ-SC 1756.82 51.18 55.32 1591.54 1482.54 333.40 466.98 5946335.65 559240.48 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ ' Company: ConocoPhillips Alaska lnc. Date: 5/17/2007 -___ Time. 10:23:43 Page: 2 Field: Ku paruk River Unit 'Co-or dinate(NE) Reference: Well: 1J-10 5, T[ue North Site: Ku paruk 1J Pad Vertical(TV D) Reference: 1J-105PB1 : 1'09 .0 Well: 1J -105 Section (VS)Reference: Well (O.OON,O:OOE,180.OOAzi} Wellpath: 1J -105P61 Survey Calc ulation Method: ___ __ - Minimum C urvat ure Db: Oracle ___ Snr.,cy MD Incl Azim TVD SysTVD N/S E/W AiapN A1apE Tool ff deg deg ft ft ft ft ft ft 1809 .45 51.26 56.92 1624. 50 1515. 50 356. 27 501. 04 5946358. 78 559274. 36 MWD+IFR-AK-CAZ-SC 1877 .54 54.55 57.79 1665. 57 1556. 57 385. 56 546. 77 5946388. 42 559319. 85 MWD+IFR-AK-CAZ-SC 'i 1904 .90 56.10 57.96 1681. 13 1572. 13 397. 52 565. 83 5946400. 53 559338. 81 MWD+IFR-AK-CAZ-SC 1955 .07 55.90 57.63 1709. 19 1600. 19 419. 69 601. 02 5946422. 97 559373. 83 MWD+IFR-AK-CAZ-SC 2000 .46 57.26 56.55 1734. 19 1625. 19 440. 28 632. 82 5946443. 80 559405. 47 MWD+IFR-AK-CAZ-SC 2035 .72 58.97 55.94 1752. 81 1643. 81 456. 91 657. 72 5946460. 63 559430. 23 MWD+IFR-AK-CAZ-SC 2094 .86 62.29 57.36 1781. 81 1672. 81 485. 23 700. 77 5946489. 28 559473. 05 MWD+IFR-AK-CAZ-SC ~ 2160 .94 64.27 57.76 1811. 52 1702. 52 516. 89 750. 58 5946521. 32 559522. 61 MWD+IFR-AK-CAZ-SC ~ 2190 .98 65.61 58.31 1824. 25 1715. 25 531. 29 773. 66 5946535. 91 559545. 58 MWD+IFR-AK-CAZ-SC 2255 .80 68.74 56.23 1849. 39 1740. 39 563. 60 823. 90 5946568. 60 559595. 56 MWD+IFR-AK-CAZ-SC ~ 2284 .90 69.79 56.29 1859. 69 1750. 69 578. 72 846. 54 5946583. 89 559618. 07 MWD+IFR-AK-CAZ-SC 2329 .52 69.74 56.72 1875. 13 1766. 13 601. 82 881. 45 5946607. 27 559652. 80 MWD+IFR-AK-CAZ-SC 2379 .75 69.84 56.48 1892. 48 1783. 48 627. 77 920. 80 5946633. 52 559691 .94 MWD+IFR-AK-CAZ-SC 2427 .93 69.71 53.78 1909. 14 1800. 14 653. 61 957. 89 5946659. 65 559728 .83 MWD+IFR-AK-CAZ-SC ~ 2475 .69 69.43 53.96 1925. 81 1816. 81 680. 00 994. 04 5946686. 31 559764 .76 MWD+IFR-AK-CAZ-SC 2573 .07 69.07 55.90 1960. 31 1851. 31 732. 32 1068. 56 5946739. 21 559838 .87 MWD+IFR-AK-CAZ-SC '; 2668 .62 69.00 55.97 1994. 50 1885. 50 782. 30 1142. 48 5946789. 76 559912 .39 MWD+IFR-AK-CAZ-SC '~~ 2761 .03 69.27 56.63 2027. 41 1918. 41 830. 21 1214. 32 5946838. 22 559983 .84 MWD+IFR-AK-CAZ-SC 2857 .69 69.10 57.13 2061. 76 1952. 76 879. 58 1289. 99 5946888. 18 560059 .12 MWD+IFR-AK-CAZ-SC 2951 .99 70.36 58.28 2094. 43 1985. 43 926. 84 1364. 76 5946936. 01 560133 .51 MWD+IFR-AK-CAZ-SC 3047 .78 68.99 55.48 2127. 71 2018. 71 975. 90 1439. 99 5946985. 66 560208 .35 MWD+IFR-AK-CAZ-SC 3141 .74 67.32 56.57 2162. 67 2053. 67 1024. 64 1512. 31 5947034. 95 560280 .28 MWD+IFR-AK-CAZ-SC 3237 .01 67.55 56.57 2199. 23 2090. 23 1073. 11 1585. 73 5947083 .99 560353 .31 MWD+IFR-AK-CAZ-SC 3345 .45 69.14 58.63 2239. 25 2130. 25 1127. 10 1670. 82 5947138 .64 560437 .97 MWD+IFR-AK-CAZ-SC 3442 .21 65.71 59.55 2276. 39 2167. 39 1172. 99 1747. 46 5947185 .13 560514 .24 MWD+IFR-AK-CAZ-SC 3537 .73 65.96 61.45 2315. 49 2206. 49 1215. 90 1823. 31 5947228 .62 560589 .75 MWD+IFR-AK-CAZ-SC 3596 .12 65.22 64.10 2339. 63 2230. 63 1240. 23 1870. 58 5947253 .31 560636 .82 MWD+IFR-AK-CAZ-SC 3633 .41 65.88 65.30 2355. 06 2246. 06 1254. 74 1901. 27 5947268 .06 560667 .40 MWD+IFR-AK-CAZ-SC 3669 .03 67.11 65.93 2369. 27 2260. 27 1268. 22 1931. 02 5947281 .77 560697 .04 MWD+IFR-AK-CAZ-SC 3728 .04 67.16 66.18 2392. 20 2283. 20 1290. 29 1980. 71 5947304 .22 560746 .55 MWD+IFR-AK-CAZ-SC 3777 .68 67.17 68.01 2411. 46 2302. 46 1308. 09 2022. 85 5947322 .36 560788 .55 MWD+IFR-AK-CAZ-SC I 3825 .12 68.49 69.59 2429. 37 2320. 37 1323. 98 2063. 81 5947338 .56 560829 .38 MWD+IFR-AK-CAZ-SC ~i 3918 .86 68.09 74.35 2464. 06 2355. 06 1350. 93 2146. 59 5947366 .15 560911 .94 MWD+IFR-AK-CAZ-SC i 4014 .42 67.11 75.39 2500. 47 2391. 47 1373. 99 2231. 88 5947389 .88 560997 .03 MWD+IFR-AK-CAZ-SC 4110 .62 67.51 80.06 2537. 60 2428. 60 1392. 85 2318. 57 5947409 .41 561083 .57 MWD+IFR-AK-CAZ-SC 4205 .78 68.38 84.20 2573. 35 2464. 35 1404. 91 2405. 91 5947422 .15 561170 .80 MWD+IFR-AK-CAZ-SC 4300 80 67 45 87 10 2609 08 2500 08 1411 59 2493 70 5947429 .52 561258 .52 MWD+IFR-AK-CAZ-SC . . . . . . . 4395 .43 68.23 92.41 2644. 79 2535. 79 1411. 96 2581. 29 5947430 .57 561346 .11 MWD+IFR-AK-CAZ-SC ~~, 4493 .63 67.18 94.70 2682. 05 2573. 05 1406 .33 2671. 97 5947425 .65 561436 .81 MWD+IFR-AK-CAZ-SG 4588 .36 68.50 96.34 2717. 78 2608. 78 1397 .89 2759. 29 5947417 .89 561524 .19 MWD+IFR-AK-CAZ-SC 4683 .41 67.55 95.81 2753. 35 2644. 35 1388 .56 2846. 94 5947409 .24 561611 .90 MWD+IFR-AK-CAZ-SC 4779 .17 68.30 99.82 2789. 35 2680. 35 1376 .49 2934. 83 5947397 .86 561699 .87 MWD+IFR-AK-CAZ-SC ~ 4872 .63 69.50 104.99 2823. 02 2714. 02 1357 .75 3019. 94 5947379 .79 561785 .12 MWD+IFR-AK-CAZ-SC 4968 .32 69.06 108.17 2856. 88 2747. 88 1332 .22 3105. 71 5947354 .93 561871 .08 MWD+fFR-AK-CAZ-SC 5065 .43 69.07 110.92 2891. 58 2782. 58 1301 .88 3191. 17 5947325 .26 561956 .77 MWD+IFR-AK-CAZ-SC 5159 .58 69.81 114.32 2924. 66 2815. 66 1267 .97 3272. 53 5947291 .99 562038 .38 MWD+IFR-AK-CAZ-SC ' 5255 .69 69.23 114.40 2958. 28 2849. 28 1230 .84 3354. 55 5947255 .50 562120 .68 MWD+IFR-AK-CAZ-SC 5349 .24 .68.78 115.10 2991. 80 2882. 80 1194 .27 3433. 86 5947219 .56 562200 .27 MWD+IFR-AK-CAZ-SC I 5444 .91 68.27 118.24 3026. 83 2917. 83 1154 .32 3513. 41 5947180 .24 562280 .11 MWD+IFR-AK-CAZ-SC ' 5539 .50 68.35 121.32 3061. 80 2952. 80 1110 .67 3589. 68 5947137 .19 562356 .72 MWD+IFR-AK-CAZ-SC 5634 .92 68.64 124.68 3096. 79 2987. 79 1062 .33 3664 .12 5947089 .43 562431 .53 MWD+IFR-AK-CAZ-SC I 5729 .60 67.81 128.24 3131. 92 3022. 92 1010 .10 3734 .83 5947037 .76 562502 .63 MWD+IFR-AK-CAZ-SC I ~: Halliburton Company Survey Report M Company: ConocoPhil{ips Alaska Inc. - __ _ Date: - -__ 5/17/20D7 Time: 10:23:43 Yagc: 3 Field: Ku paruk River Unit < `Co-ordinate(I~?E) Reference: Well: 1 J-10 5, Tr ue North Sitc: Ku paruk 1J Pad Vertical (TVD)Beference: 1J-105PB1 : 109 .0 Well: 1J -105 Sectio n (VS)Reference: Well (O.OON,D.OOE,180.DOAzi} Wellpath: 1J -105PB1 __ Survey Calculati on Method: ___ Minimum C urvat ure Db: OtaCle ___ Survey MD Incl Azim TVD Sys T~~ D N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 5821.68 68.00 131. 77 3166. 56 3057 - .56 - _ 955. 26 3800.16 __ 5946983. 44 562568. 39 MWD+IFR-AK-CAZ-SC 5917.84 67.17 133. 65 3203. 23 3094 .23 894. 97 3865.48 5946923. 67 562634. 17 MWD+IFR-AK-CAZ-SC 6013.13 67.29 136. 78 3240. 12 3131 .12 832. 62 3927.37 5946861. 81 562696. 53 MWD+IFR-AK-CAZ-SC 6107.84 66.97 139. 97 3276. 94 3167 .94 767. 40 3985.33 5946797. 05 562754. 99 MWD+IFR-AK-CAZ-SC 6204.07 66.40 144. 53 3315. 04 3206 .04 697. 55 4039.42 5946727. 63 562809. 62 MWD+IFR-AK-CAZ-SC 6298.64 67.96 148. 24 3351. 73 3242 .73 624. 97 4087.65 5946655. 44 562858. 41 MWD+IFR-AK-CAZ-SC ~ 6392.55 68.51 151. 67 3386. 56 3277 .56 549. 49 4131.30 5946580. 30 562902. 65 MWD+IFR-AK-CAZ-SC 6487.79 68.90 155. 54 3421. 16 3312 .16 470. 02 4170.74 5946501. 15 562942. 70 MWD+IFR-AK-CAZ-SC i 6583.62 68.87 159. 34 3455. 69 3346 .69 387. 48 4205.03 5946418. 90 562977. 63 MWD+IFR-AK-CAZ-SC 6680,00 68.68 161. 33 3490. 59 3381 .59 302. 89 4235.26 5946334. 55 563008. 52 MWD+IFR-AK-CAZ-SC 6775.36 72.18 163. 40 3522. 53 3413 .53 217. 27 4262.46 5946249. 15 563036. 38 MWD+IFR-AK-CAZ-SC 6870.19 76.19 165. 88 3548. 37 3439 .37 129. 31 4286.60 5946161. 39 563061. 21 MWD+IFR-AK-CAZ-SC 6965.40 76.34 167. 67 3570. 98 3461 .98 39. 28 4307.76 5946071. 54 563083. 06 MWD+IFR-AK-CAZ-SC 7061.58 78:85 169. 66 3591. 64 3482 .64 -52. 81 4326.21 5945979. 60 563102. 23 MWD+IFR-AK-CAZ-SC 7158.09 81.49 169. 82 3608. 12 3499 .12 - 146. 38 4343.14 5945886. 18 1 5631 9. 90 WD+IFR-AK- AZ- M C SC 7253.50 81.96 171. 51 3621. 85 3512 .85 -239. 54 4358.46 5945793. 15 563135. 93 MWD+IFR-AK-CAZ-SC 7347.33 80.49 173. 38 3636. 16 3527 .16 -331. 46 4370.65 5945701. 34 563148. 85 MWD+IFR-AK-CAZ-SC 7473.00 80.49 173. 38 3656. 93 3547 .93 -454. 57 4384.94 5945578. 35 563164. 09 PROJECTED to TD ~ Time Logs --- IDate From To Dur S. De th E De th Phase Code Subcode T COM 03/22/2007 00:00 12:00 12.00 288 1,007 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 288' to 1,007' MD/988' TVD (719') ART 1.76 hrs, AST 5.09 hrs, took 7 add. Gyro surveys taking approx 1 3/4 hrs. last G ro was taken at 826'. 12:00 00:00 12.00 1,007 2,133 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 1,007' to 2,133' MD/1,798' ND 1,126' ART 2.35 hrs, AST 6.0 hrs, 03/23/2007 00:00 13:15 13.25 2,133 3,396 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 2,133' to 3,396 MD/2,256' TVD 1,263') (10 3/4" csg pt.) ART 5.72 hrs, AST 2.48 hrs. 13:15 13:45 0.50 3,396 3,396 SURFA DRILL CIRC P Circ hole to clear BHA and monitored well-static. 13:45 14:45 1.00 3,396 2,640 SURFA DRILL REAM NP Backreamed out of hole from 3,396' to 2,640', 80 rpm's, 590 gpm at 1,750 si. 14:45 15:15 0.50 2,640 3,396 SURFA DRILL TRIP NP RIH from 2,640' to 3,323', st wt up 100K, do wt 72K, then washed to btm at 3,396'. 15:15 16:30 1.25 3,396 3,396 SURFA DRILL CIRC NP Circ btms up at 3,396'then spotted 101 bbl MI tube pill in open hole to cover btm 500' of hole. circ at 590 gpm at 1,700 psi and at 80 rpm's, monitored well-static, blew down top drive. 16:30 20:00 3.50 3,396 714 SURFA DRILL REAM P POOH from 3,396' to 2,670', then BROOH from 2,670' to 816', then pumped out of hole to ghost reamer at 714', BROOH at 590 mat 80 r m's. 20:00 20:15 0.25 714 714 SURFA DRILL CIRC P Circ btms up at 714', circ at 500 gpm and 1,100 si. 20:15 21:00 0.75 714 165 SURFA DRILL TRIP P LD ghost reamer and POOH to 165' standin back HWDP and ~ars. 21:00 23:00 2.00 165 0 SURFA DRILL PULD P POOH from 165' LD BHA #1, LD NMFDC's, MWD and motor 23:00 00:00 1.00 0 0 SURFA DRILL OTHR P Cleared BHA from rig floor and cleaned same. 03/24!2007 00:00 02:15 2.25 0 0 SURFA CASIN RURD P RU to run 10 3/4" csg, changed out elevator bales and MU Franks fill up tool, made dummy run with hanger and landin 't. 02:15 02:30 0.25 0 0 SURFA CASIN( SFTY P Held PJSM with rig crew and tong operator on csg running details and hazard assessment for the 'ob. 02:30 07:45 5.25 0 2,900 SURFA CASIN RNCS P MU 3 jts 10 ?" 45.5#, L-80 BTC csg and shoe track and thread locked same RIH 80' and checked floats. Cont. RIH with 10 3/4" 45.5#, L-80, BTC csg to 2900', filled csg with MI tube 776 1.5% while RIH. 07:45 08:30 0.75 2,900 2,900 SURFA CASIN( CIRC NP Circ 1 csg cap. Staging pump rate up to 7 bpm at 380 psi to spot mud treated with MI tube 776 in annulus, S/0= 100k, P/U =125K. . _-___ _. ®m_e..~. ~'a~~~a ? of 3 I Time Logs _Date From To Dur S De th E De th Phase Code Subcode T COM i 03/24/2007 08:30 09:15 0.75 2,900 3,387 SURFA CASIN RNCS P Cont to RIH and landed csg at 3,386.76', na problems RIH, ran 85 total jts of csg then MU Vetco Gray hanger and landed csg in the hanger, (total length = 3356.27') initial P/U = 150k, S/O = 100k. Ran 25 bowspring centralizers with 3 stop rings per well plan, Landed 10 3/4"csg on the han er. 09:15 10:00 0.75 3,387 3,387 SURFA CEMEI~ CIRC P Circ bottoms up thru Franks fill up tool staging pump rate up to 70 spm, 7 bpm at 400 psi, reciprocated pipe (P/U = 150k, S/0=120k 10:00 10:45 0.75 3,387 3,387 SURFA CEME RURD P RD Franks fill up tool and MU Dowell cement head. 10:45 13:15 2.50 3,387 3,387 SURFA CEME CIRC P Cont to Circ and condition mud for cementing, staged pump rate up to 7 bpm at 400 psi, initial mud was 9.7 ppg, 183 vis, PV 29 and YP of 48, conditioned mud to 9.2 ppg, 38 vis, PV 15 andYP9. 13:15 13:30 0.25 3,387 3,387 SURFA CEME SFTY P Held PJSM with crew, Dowell and ASRC truck drivers on cement job while Circ. 13:30 16:00 2.50 3,387 3,387 SURFA CEME DISP P Dowell pumped 10 bbls of CW 100 then pressure tested lines to 3,500 psi, cont to pump 40 add. Bbls of CW 100 at 8.3 ppg, Dropped bottom plug and pumped 50 bbls of 10.5 ppg mudpush with red dye at 4 bpm at 225 psi.. Mixed and pumped 488 bbls, 600 sx of Arctic set lite cement at 10.7 ppg and 4.57 yield with additives at 6.3 bpm at 500 psi, Ceased reciprocating casing and landed hanger in landing ring. 163 barrels of lead slurry were outside of casing when reciprocation stopped. Continued mixing and pumping 87.8 bbls, 198 sx of Deepcrete cement at 12.0 ppg and 2.47 yield with additives at 5.5 bpm at 930 psi.. Shut down and dro ed to lu . 16:00 17:00 1.00 3,387 3,387 SURFA CEME DISP P Dowell chased plug with 20 bbls of water then turned it over to the rig and rig cont. to displace cement with 9.2 ppg mud at 5.6 bpm, initial pressure was 600 psi, max pressure at 5.5 bpm was 680 psi, bumped plug on calc displacement of 297 bbls, pressured up to 1,500 psi and held for three minutes, bled off and checked floats-OK. CIP at 17:00 hrs, had 143 bbls of good 10.7 ppg cement back at surface. ~_~._ F'a~~: 3 ~f 3~ s ~ Time Lomas _ Date From To Dur S De th E De th Phase Code Subcode T COM 03/24/2007 17:00 19:30 2.50 3,387 3,387 SURFA CEME~ RURD P Flushed out diverter and lines, RD csg equip, LD cement head and landing jt, cleared ri floor. 19:30 21:30 2.00 3,387 3,387 SURFA WELCT NUND P Held PJSM then ND riser, diverter, knife valve and line and set out of cellar. 21:30 23:00 1.50 3,387 3,387 SURFA WELCT NUND P Oriented and NU Vetco Gray MB 222 wellhead, tested seals to 5,000 psi for 10 min. 23:00 00:00 1.00 3,387 3,387 SURFA WELCT NUND P Began to NU BOP's. 03/25/2007 00:00 01:45 1.75 0 0 SURFA WELCT NUND P Fin. NU BOPE and riser 01:45 08:30 6.75 0 0 SURFA WELCT BOPE P RU and tested BOPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high including annular. Tested with 4", 5" and 7 5/8" test jts, tested alarms and Koomey, initial press. 3,000 psi, 1,750 psi after functioning rams, took 47 sec. to gain 200 psi, 3 min 28 sec. for full recovery. 5 nitrogen bottles ave 2,000 psi. Note: Chuck Scheve with AOGCC waived witnessin of the test. 08:30 09:15 0.75 0 0 SURFA DRILL OTHR P Installed wear bushing 09:15 10:30 1.25 0 0 SURFA DRILL PULD P LD 12 jts of excess HWDP out of the derrick. 10:30 12:00 1.50 0 0 SURFA RIGMN SVRG P Held PJSM then slip and cut 78' of drl line, serviced to drive. 12:00 12:15 0.25 0 0 SURFA DRILL SFTY P Held PJSM with Sperry Sun on MU BHA #2 12:15 15:00 2.75 0 357 SURFA DRILL PULD P MU 9 7/8" BHA #2 RIH to 357', MU bit #2 on 7" motor with 1.5 deg. bend, MU MWD and oriented and uploaded same, RIH with NMFDC's, HWDP and 'ars. 15:00 17:45 2.75 357 3,295 SURFA DRILL TRIP P RIH with BHA #2, PU 93 jts of 5" DP out of the pipe shed while RIH from 357' to 3,295', 17:45 18:45 1.00 3,295 3,295 SURFA DRILL CIRC P Circ btms up evening MW in and out at 9.15 18:45 19:45 1.00 3,295 3,295 SURFA DRILL SFTY P Held combination stripping and well kill drill with crew, had good pre and post discussion with tourpusher and crew. Blew down choke and lines. 19:45 21:00 1.25 3,295 3,295 SURFA CASINC DHEQ P RU and tested 10 3/4" csg to 3,000 si for 30 min, ood test. 21:00 22:15 1.25 3,295 3,396 SURFA CEME~ COCF P RIH and tagged plugs at 3,299' (FC @ 3,304') drilled out plugs, FC, shoe track and flt shoe then cleaned out to TD at 3,396', 2K WOB, 70 rpm's, 513 m at 1,400 si. 22:15 22:30 0.25 3,396 3,416 SURFA DRILL DRLG P Drilled 20' of new hole from 3,396' to 3,416' MD/2,263' TVD ADT .08hrs. 22:30 23:00 0.50 3,416 3,416 SURFA DRILL CIRC P Displaced hole over from spud mud to reconditioned 9.0 mud. ~~ ~~ ~ __ ~ ® ~as~~ ~ ~f ~a ~ Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 03/25/2007 23:00 00:00 1.00 3,416 3,416 SURFA DRILL LOT P RU and performed a LOT to 14.2 ppg EMW, 615 psi, at 2,254' TVD with 9.0 p MW 03/26/2007 00:00 00:15 0.25 3,416 3,416 SURFA DRILL LOT P Fin RD and blowing down lines after erformin LOT. 00:15 12:00 11.75 3,416 4,533 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with 1.5 deg motor from 3,416' to 4,533' MD/ 2,694' TVD (1,117') ART 2.46 hrs, AST 3.72 hrs, est clean hole ECD at 9.4 ppg, ave MW 9.0 ppg, ave ECD 9.9 ppg, ave BGG 40 units, max gas 73 units. 12:00 00:00 12.00 4,533 5,769 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with 1.5 deg motor from 4,533' to 5,769' MD/ 3,145' TVD (1,236') ART 4.19 hrs, AST 3.74 hrs, ave MW 9.15 ppg, ave ECD 10.3 ppg, ave BGG 70 units, max gas 318 units, pumped hi vis sweeps at 4,650' and 5,250' and had 15% increase in cuttings back from the swee s 03/27/2007 00:00 12:00 .12.00 5,769 6,659 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with 1.5 deg motor from 5,769' to 6,659' MD/ 3,482' ND (890') ART 2.13 hrs, AST 5.17 hrs, ave MW 9.15 ppg, ave ECD 10.3 ppg, ave BGG 60 units, max gas 744 units from Ugnu B, caused screens to blind off also. Drilled at a reduced ROP due to phase 3 and truck availabilit . 12:00 23:00 11.00 6,659 7,473 INTRMI DRILL DDRL P Directionally drilled 9 7/8" hole with 1.5 deg motor from 6,659' to 7,473' MD/ 3,656' TVD (814') ART 4.33 hrs, AST 3.49 hrs, ave MW 9.2 ppg, ave ECD 10.7 ppg, ave BGG 50 units, max gas 87 units. Pumped hi vis sweep at 7,240' and had 15% increase in cuttings., drilled thru 2 concretions for 5'. 23:00 23:45 0.75 7,473 7,473 INTRM1 DRILL OTHR T While drilling on concretion at 7,473' motor stalled, PU and everything ck'd ok, went back to btm and attempted to cont. to drill when motor stalled a 2nd time, PU 15' off btm and had a 400 psi pressure loss, went back down rotating and set 15K do at 7,460' and had a increase in torque of 5-6K ft-Ibs, up from 9K to14-15K ft-Ibs and saw pressure increase, PU again and saw pressure drop off again, set down high again with no rotation or increase in pressure, able to get MWD signal and appears motor may have possibly twisted off, PU again and cont. to see 400 psi drop. Decision was made to POOH. • l J Time Logs Date From To Dur S De th E. De th_ Phase Code Subcode T COM 03/27/2007 23:45 00:00 0.25 7,473 7,473 INTRM1 DRILL OWFF T Monitored well-static. 03/28/2007 00:00 05:15 5.25 7,473 357 INTRM1 DRILL TRIP T Pumped out of the from 7,473' to 5,400', pumped out at 217 gpm at 400 psi, POOH on elevators from 5,400' to csg shoe, monitored well-static, pumped dry job and cont to POOH to BHA at 357'. 05:15 07:15 2.00 357 0 INTRM1 DRILL PULD T POOH standing back HWDP, jars and NMFDC's, POOH with MWD and motor housing. Found bit, bit box, lower stab., lower bearing and adjustable housing missing along with the rotor shaft from inside the motor, approx 22' of fish left in the hole, est TOF at 7,451'. Downloaded MWD and fin. LD BHA and clearing rig floor. NOTE: The decision was made to sidetrack well due to the cost of the motor verses the rig time to fish and the possiblity of not even being able to recover the fish in 1 run. 07:15 09:15 2.00 0 357 INTRM1 DRILL PULD T MU 9 7/8" BHA #3 RIH to 357', MU new bit and 7" motor with 1.5 deg bend, MU MWD and oriented and uploaded same, RIH with HWDP, jars and NMFDC's to 357' and shallow tested MWD. 09:15 11:15 2.00 357 3,679 INTRM1 DRILL TRIP T RIH with BHA #3 from 357' to 3,679' when we lost all down wt. (10 3/4" shoe at 3,387') Probably lost down wt due to not cleanin hole on tri out. 11:15 15:15 4.00 3,679 7,071 INTRM1 DRILL REAM T Washed and reamed from 3,679' to KOP at 7,071', washed and reamed at 80 r m's, 237 mat 900 si 15:15 15:30 0.25 7,071 7,071 INTRM1 DRILL CIRC T Obtained SPR's then oriented tool face to 150 R for sidetrack 15:30 16:15 0.75 7,071 7,111 INTRM1 DRILL DDRL T Troughed well for sidetracking, troughed from 7,071' to 7,111' (KOP at 7,071' MD/ 3,593' TVD 16:15 00:00 7.75 7,111 7,473 INTRMI DRILL DDRL T Cont. to sidetrack well from 7,111' to 7,473' MD/ 3,663' (orig. hole depth) ART 3.97 hrs, AST 1.67 hrs, 9.25 ppg MW, ave ECD 10.0 ppg, ave BGG 70 units, max gas 228 units. Drilled 2-concretions for 17'. 03/29/2007 00:00 12:00 12.00 7,473 8,433 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with 1.5 deg motor from 7,473' to 8,433' MD/ 3,804' TVD, (960') ART 5.15 hrs, AST 2.06 hrs, ave MW 9.25 ppg, ave ECD 10.7 ppg, ave BGG 80 units, max as 176 units. _ _ -~- ~ ___~ ~ ~m ~_ 1~~~ ~ ct ~~ Time Logs Date __ _ From To Dur S Depth E_ Depth Phase Code Subcode T COM _ 03/29/2007 12:00 19:00 7.00 8,433 8,843 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with 1.5 deg motor from 8,433' to 8,843' MD/ 3,820' TVD, (410') (7 5/8" csg pt) ART 3.21 hrs, AST 1.87 hrs, ave MW 9.3 ppg, ave ECD 10.5 ppg, ave BGG 50 units, max as 173 units. 19:00 19:15 0.25 8,843 8,843 INTRM1 DRILL CIRC P Circ to clear BHA, took survey on btm and SPR's. 19:15 19:30 0.25 8,843 8,818 INTRM1 DRILL OWFF P Monitored well-static, LD single PU to TD well 19:30 00:00 4.50 8,818 6,057 INTRMI DRILL REAM P Backreamed out of hole from 8,818' to 6,057', BROOH at 600 gpm, 2,000 psi and 85 rpm's, attempted to pull 1 BROOH 1 at 6,915' and hole swabbing with 25-30K drag, cont to BROOH to 6,057'. 03!30/2007 00:00 02:30 2.50 6,057 3,387 INTRM1 DRILL REAM P Cont to BROOH to the shoe, BROOH from 6,057' to 5,488' then pulled 1 and BR-1 to 4,400 and was getting large amount of cuttings back, BROOH to 3,869' then cont to pull 1-BR 1 to shoe at 3,387', BROOH at 600 gpm, 2,000 si and 85 r m's. 02:30 03:30 1.00 3,387 3,387 INTRM1 DRILL CIRC P Pumped 30 bbl hi vis sweep and circ hole clean at 3,387', circ hole at 600 gpm at 1,600 psi and 60 rpm's, had 25% increase in cuttings back from the sweep, circ 3X btms up and was clean at the shakers. 03:30 03:45 0.25 3,387 3,387 INTRM1 DRILL OWFF P Monitored well-static, pumped dry job and blew down to drive. 03:45 05:00 1.25 3,387 204 INTRM1 DRILL TRIP P POOH from 3,387' to 204' standing back HWDP and 'ars. 05:00 08:00 3.00 204 0 INTRM1 DRILL PULD P POOH LD NMFDC's, downloaded MWD then fin LD BHA #3 and cleared ri floor. 08:00 08:15 0.25 0 0 INTRM1 DRILL PULD P Pulled wear bushing. 08:15 09:30 1.25 0 0 INTRM1 CASIN RURD P RU to run 7 5/8" csg, changed out elevator bales and MU Franks fill up tool. 09:30 09:45 0.25 0 0 INTRM1 CASINC SFTY P Held PJSM with rig crew and tong o erator on runnin of cs . 09:45 15:30 5.75 0 3,392 INTRM1 CASINC RNCS P RIH with 7 5/8" csg to 3.392' (csg shoe at 3,387') MU 3 jts 7 5/8" 29.7#, L-80 BTCM csg and shoe track and thread locked same RIH 85' and checked floats. Cont. RIH with 7 5/8" 29.7#, L-80, BTCM cs to 3,392" 15:30 16:15 0.75 3,392 3,392 INTRM1 CASINC CIRC P Circ btms up at 3,392' then spotted 48 bbl Steel Lube pill in the annulus. Circ at 4 bpm, 320 psi, st wt up 99K, do wt 75K ~~~ ~ ~~ ( ~ar~ ? o~ 3~ Time Lo s _. 9.- -- Date____ From To Dur _ S Depth_E. De th Phase Code Subcode__ T_ COM _ 03/30/2007 16:15 23:00 6.75 3,392 8,838 INTRM1 CASIN( RNCS P Cont to RIH with 7 5/8" csg and tagged btm, PU and set csg on depth at 8,838', no problems RIH, ran 206 total jts of csg with 5 pup jts to place csg and window jts on depth, initial string wt up 190K and down wt 68K. Ran 90 tandem rise bowspring centralizers with 38 stop rings per well Ian. 23:00 00:00 1.00 8,838 8,838 INTRM1 CEME CIRC P Began to circ and cond. mud for cementing, circ btms up thru the Franks tool, staged pump rate up to 4 b mat 700 si. 03/31/2007 00:00 01:00 1.00 8,838 8,838 INTRM1 CEME CIRC P Cont to circ a btms up thru the Franks fill up tool, staged pump rate up to 6 bpm at 700 psi, st wt up 205K, do wt 55K 01:00 01:30 0.50 8,838 8,838 INTRM1 CEME RURD P RD Franks fill up tool and MU Dowell cement head. 01:30 03:00 1.50 8,838 8,838 INTRMI CEME CIRC P Cont to circ and condition mud for cementing, staged pump rate up to 6 bpm at 600 psi, initial mud was 9.5 ppg, 68 vis, PV 17 and YP of 28, conditioned mud to 9.05 ppg, 44 vis, PV 8 and YP 12, St wt up 230K, Dn wt 75 03:00 03:15 0.25 8,838 8,838 INTRM1 CEME SFTY P Held PJSM with crew, Dowell and ASRC vac truck drivers on cement 'ob. 03:15 04:30 1.25 8,838 8,838 INTRM1 CEME DISP P Dowell pumped 10 bbls of CW 100 then pressure tested lines to 3,500 psi, cont to pump 20 add. bbls of CW 100 at 8.3 ppg and pumped 30 bbls of 10.5 ppg mudpush at 4 bpm at 200 psi.. Dropped btm plug. Mixed and pumped 192 bbls, 480 sx of Deepcrete cement at 12.5 ppg and 2.25 yield with additives, ave 5.25 bpm at 250 psi, reciprocated casing. Dropped top lu . 04:30 06:00 1.50 8,838 8,838 INTRM1 CEME DISP P Rig displaced cement with 8.4 ppg MOBM at 6 bpm, initial pressure was 250 psi, max pressure at 6 bpm was 1,150 psi, stopped reciprocating pipe 287 bbls into displacement when we lost all down wt, had 76 bbls of cement out of the shoe, slowed to 3 bpm and pumped talc displace of 402 bbls plus ?shoe track and plug did not bump. Shut down with 850 psi, held for three minutes, bled off and checked floats-OK. Had good returns through out the job, talc TOC @ 4,927'. CIP at 05:45 hrs. 06:00 06:30 0.50 8,838 8,838 INTRM1 WELC NUND P ND wellhead v _~ _~ ® _ ~ ~~c;e ~ ~~ 35 ~~__w ~~ Time Lomas __ _ __ Date From To Dur S De th E. De th Phase Code Subcode T COM 03/31/2007 06:30 08:45 2.25 8,838 8,838 INTRM1 WELCT EQRP P Lifted up on stack and wellhead, installed 7 5/8" csg slip, setting same with 70K st wt. Cut off csg and installed ackoff. 08:45 09:15 0.50 8,838 8,838 INTRM1 WELCT NUND P NU wellhead. 09:15 10:15 1.00 8,838 8,838 INTRM1 WELCT OTHR P RU and tested 7 5/8" packoff and wellhead flange to 3,800 psi for 10 min and ck'd ok. Sim-op Installed wear bushin 10:15 12:00 1.75 8,838 8,838 INTRM1 DRILL OTHR P RU on 10 3/4" x 7 5/8" annulus and performed infectivity test then flushed annulus with 160 bbls water, ave 2.5 b m, ICP 300 si, FCP 477 si. 12:00 14:00 2.00 8,838 8,838 INTRM1 DRILL OTHR P Changed out saver sub on top drive to 4" and changed out pump liners from 6" to 5 1/2". 14:00 14:15 0.25 8,838 8,838 INTRMI DRILL SFTY P Held PJSM on LD DP out of the derrick and the hazards associated with the 'ob. 14:15 21:00 6.75 8,838 8,838 INTRM1 DRILL PULD P LD 89 stds of 5" DP and 2 stds of HWDP and jars out of the. derrick thru the mousehole. 21:00 00:00 3.00 8,838 8,838 INTRM1 DRILL OTHR P Unloaded remaining 5" DP out of the pipe shed and loaded 160 jts of 4" DP into the shed and began to strap same. 04/01/2007 00:00 01:30 1.50 0 0 INTRM1 DRILL OTHR P Fin. loading pipe shed with 4" DP, Dc's and HWDP, stra ed same. 01:30 06:00 4.50 0 0 INTRM1 DRILL PULD P PU and RIH with 13 stds of Hybrid push pipe and 6 stds of HWDP and 'ars, POOH and stood back. 06:00 06:15 0.25 0 0 INTRM1 DRILL SFTY P Held PJSM with roustabouts on PU and handlin 4" DP. 06:15 09:30 3.25 0 0 INTRM1 DRILL PULD P PU and RIH with 111 jts of 4"slick DP (37 stds), POOH and stood back 15 stds DP. 09:30 10:30 1.00 0 0 INTRM1 DRILL SFTY P Held stripping and well kill drill with crew, circ. thru choke during drill, blew down same. 10:30 12:00 1.50 0 0 INTRMI DRILL PULD P POOH and stood back 22 stds of 4" DP and cleaned ri floor. 12:00 12:15 0.25 0 0 INTRM1 DRILL SFTY P Held PJSM with Sperry Sun and rig crew on MU Geo ilot BHA. 12:15 15:30 3.25 0 461 INTRMI DRILL PULD P MU 6 3/4" BHA #4 RIH to 461', MU 6 3/4" bit #4 with Geopilot and MWD, uploaded MWD and RIH with BHA to 368', RIH with 4" DP to 461' and shallow tested MWD and broke in Geo ilot. 15:30 16:00 0.50 461 461 INTRM1 DRILL SFTY P Held stripping and well kill drill with crew, circ. thru choke during drill, blew down same. 16:00 21:45 5.75 461 7,555 INTRM1 DRILL PULD P RIH with BHA #4 PU 4" DP out of the pipe shed, RIH with 96 slick jts of 4" DP and 135 jts with supersliders to 7, 555' ~® ~ ~e ~ e~ ~ag~ 9 r~; 3 s ~ .J • Time Logs Date From To D_ur S De th E. De th Phase Code Subcode T COM ~ 04/01/2007 21:45 23:15 1.50 7,555 7,555 INTRM1 RIGMN SVRG P Held PJSM then slip and cut 65' of drl line and serviced to drive. 23:15 00:00 0.75 7,555 8,676 INTRM1 DRILL TRIP P RIH out of derrick from 7,555' to 8,676' 04/02/2007 00:00 00:15 025 8,676 8,748 INTRM1 DRILL TRIP P RIH from 8,696' washing down at 1 bpm and tagged plugs above float collar at 8,748' FC at 8,750' 00:15 00:45 0.50 8,748 8,748 INTRM1 DRILL CIRC P Circ btms up for csg test, circ at 310 gpm, 2,650 psi, 70 rpm's and 5K ft-Ibs torque, rot wt 70K, up wt 150K, do wt 62K. 00:45 02:30 1.75 8,748 8,748 INTRM1 CASINC DHEQ P Stood back 1 std of DP, RU and tested 7 5/8" csg to 3,000 psi for 30 min. NOTE: After testing 7 5/8" csg to 3,000 psi, both DP and HCR valves were closed for the test, after the test the driller bled off pressure from the drill pipe and forgot to open the HCR valve, he proceeded to open VBR rams and with the pressure below they would not open. After determining the HCR valve was still closed the rig crew opened the HCR valve and bled the pressure off then the rams opened back u . 02:30 04:00 1.50 8,748 8,843 INTRM1 CEMEt` COCF P Drilled out plugs, float collar at 8,750', shoe track and flt shoe at 8,838', cleaned out to TD at 8,843'. 04:00 04:45 0.75 8,843 8,866 INTRM1 DRILL DDRL P Drill 23' of new hole to 8866'. On concretion at 8866'. 04:45 05:45 1.00 8,866 8,866 INTRM1 DRILL CIRC P Circ hole clean for LOT evening MW in and out at 8.4 ppg. circ at 300 gpm, 2,500 psi, 70 rpm's, with 5-7K ft-Ibs for ue. 05:45 06:15 0.50 8,866 8,866 INTRMI DRILL LOT P RU and performed LOT to 12.5 ppg EMW, 820 psi at 3,821' TVD with 8.4 ppg MOBM. NOTE: Decision was made to test VBR rams after pulling thru VBR's after csg test, called out storm acker. 06:15 10:00 3.75 8,866 7,835 INTRM1 DRILL WOEO T POOH 10 stds to 7,835' while W.O. storm acker, MU test lu to test ~t. 10:00 12:00 2.00 7,835 7,928 INTRM1 DRILL PULD T MU Baker storm pkr and RIH to 93' settin same bit at 7,928') __ __.. ~e ~ _-~__~e _ ~ ~~~~, 1~ tz~ 35 Time Logs Date From To Dur S. De th E_ De th Phase Code Subcode T COM 04/03/2007 21:00 00:00 3.00 7,555 8,868 PROD1 DRILL TRIP T RIH from 7,555' installing 1 super slider per jt., while RIH to 8,401' and lost down wt, cont to rotate down at 30 rpm's and 5-6k ft-Ibs torque while addin sliders to 8,868'. 04/04/2007 00:00 01:00 1.00 8,868 9,658 PROD1 DRILL REAM P Washed and reamed from 8,868' to btm at 9,658', added 1 Superslider per jt. while washing to btm. washed at 130 gpm at 650 psi, 50 rpm's and 5-8k ft-Ibs for ue 01:00 12:00 11.00 9,658 10,200 PROD1 DRILL DDRL P Drilled 6 3/4" hole in A2 sand with Geopilot from 9,658' to 10,200' MD/ 3,809' ND (542') ADT 7.36 hrs, ave MOBM MW 8.45 ppg, ave ECD 10.55 ppg, ave BGG 60 units, max gas 136 units, drilled thru 5 concretions for 31'. Pumped wt'd hi vis sweep (2# over MW) at 10,150' and had a 15% increase in cuttin s from the swee . 12:00 00:00 12.00 10,200 11,078 PROD1 DRILL DDRL P Drilled 6 3/4" hole in A2 sand with Geopilot from 10,200' to 11,078' MD/ 3,812' ND (878') ADT 7.14 hrs, ave MOBM MW 8.4 ppg, ave ECD 10.8 ppg, ave BGG 50 units, max gas 136 units, drilled thru 9 concretions for 37'. Pumped wt'd hi vis sweep (2# over MW) at 11,008' and had a 10% increase in cuttings from the sweep. PU an additional 51 Supersliders while drl , 246 total in hole. 04/05/2007 00:00 07:30 7.50 11,078 11,735 PROD1 DRILL DDRL P Drilled 6 3/4" hole in A2 sand with Geopilot from 11,078' to 11,735' MD/ 3,823' ND (657') ADT 5.0 hrs, A2 Lat T.D. ave MOBM MW 8.4 ppg, ave ECD 11.25 ppg, ave BGG 60 units, max gas 252 units, drilled thru 2 concretions for 12'. Pumped wt'd hi vis sweep (1# over MW) at 11,552' and had a 10% increase in cuttings from the swee . 07:30 07:45 0.25 11,735 11,735 PROD1 DRILL OWFF P Monitored well-static, took SPR's 07:45 12:15 4.50 11,735 8,769 PROD1 DRILL REAM P Backreamed out of hole from 11,735' to 8,769' (shoe @ 8,838'). BROOH at 320 gpm, ICP 3,150 psi, FCP 2,650 psi at 110 rpm's, no problems BROOH. 12:15 13:45 1.50 8,769 8,769 PROD1 DRILL CIRC P Pumped 30 bbl wt'd hi vis sweep (2# over MW) at 8,769' and circ hole clean, had 10% increase in cuttings back from sweep, circ an additional 2X btms up and was clean at the shakers. Circ at 320 mat 2,650 si ~ ~___~_.. ~ _ ~_._ ~~._. m...~. ~ Page 1 ~ raf 3~ • e Logs Da e From To Dur S. De th E. De th Phase Code Subcode T COM_ 04/05/2007 13:45 16:45 _ 3.00 8,769 11,735 PROD1 DRILL TRIP P RIH from 8,769' loosing down wt. at 9,983', washed and reamed to btm at 11,735', washed down at 180 gpm, 1,200 psi and 80 rpm's. No problems RIH. 16:45 19:00 2.25 11,735 11,735 PROD1 DRILL CIRC P Pumped 30 bbl wt'd hi vis sweep (1# over MW) at 11,735' and circ hole clean, had 5% increase in cuttings back from sweep, circ an additional btms up after sweep was out of hole and was clean at the shakers. Circ at 300 gpm at 2,950 psi and 100 rpm's, st wt u 125K, rot wt 60K. 19:00 20:30 1.50 11,735 11,735 PROD1 DRILL CIRC P Displaced hole over from 8.45 ppg MOBM to 8.4 ppg SFMOBM, st wt up 110K, rot wt 70K. 20:30 20:45 0.25 11,735 11,735 PROD1 DRILL OWFF P Monitored well-static, dropped 1 13/16" rabbit. 20:45 00:00 3.25 11,735 6,435 PROD1 DRILL TRIP P POOH on elevators from 11,735' to 6,435' 04/06/2007 00:00 02:45 2.75 6,435 85 PROD1 DRILL TRIP P POOH on elevators from 6,435', stood back HWDP, jars and NMFDC's POOH to 85', talc hole fill 69 bbls, actual 78 bbls 02:45 05:15 2.50 85 0 PROD1 DRILL PULD P Downloaded MWD and fin. LD BHA #5, cleared ri floor 05:15 05:30 0.25 0 0 COMPZ EVALVb SFTY P Held PJSM with rig crew and Schlumberger personnel on RU and runnin of bond to . 05:30 07:15 1.75 0 102 COMPZ EVAL PULD P RU SWS wireline and scheaves, MU USIT bond logging and tractor tool assembl RIH to 102' 07:15 09:45 2.50 102 8,700 COMPZ EVALV~ ELOG P RIH with logging tools to 6,950' then tractored down to 8,700' FC at 8,750' 09:45 12:30 2.75 8,700 3,000 COMPZ EVAL ELOG P Ran bond log from 8,700' up to 3,000', est. TOC at 4,327'. 12:30 13:30 1.00 3,000 0 COMPZ EVAL PULD P POOH from 3,000' and LD logging tools, RD SWS. 13:30 14:15 0.75 0 0 COMPZ CASINC RURD P RU to run 4 1/2" completion 14:15 14:45 0.50 0 0 COMPZ CASINC SFTY P Held PJSM with rig crew and tong operator on liner detail and associated hazards of PU liner. 14:45 18:30 3.75 0 3,918 COMPZ CASINC PUTS P PU and RIH with 4 1/2" liner to 3,918', RIH with 59 jts of blank and 31 jts of slotted 11.6 ppf L-80 BTC csg per well plan, ran 89 EZEE glider centralizer per jt wit 89 stop rings placed in the middle of the jt. MU Baker ZXP hanger assembly, st wt up 65K, do wt 56, rot wt 60K, rotated at 20 rpms with 1 K ft-Ibs for ue. 18:30 21:30 3.00 3,918 8,774 COMPZ CASINC RUNL P RIH with 4 1/2" liner from 3,918' to 8,774' (shoe at 8,838') est circ at 2.5 bpm, 225 psi, 20 rpm's with 4-5K ft-Ibs torque, st wt up 130K, do wt 70K, rot wt 77K. _~~~e ~.___-°____® -........._ ~~ x~: ~3 z~~ s5 • i Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/06/2007 21:30 00:00 2.50 8,774 11,725 COMPZ CASIN RUNL P Cont. to RIH with liner on 4" DP from 8,774' and tagged btm at 11,735', PU to liner setting depth of 11,725'. liner up wt 195K, do wt 65K, blk wt 35K, no problems running liner in open hole or rotation needed to get liner to btm, ran liner with 66 stds of 4" DP with super sliders, 13 stds Hybrid push pipe and 5 stds of HWDP. 04/07/2007 00:00 00:30 0.50 11,725 11,725 COMPZ CASIN( CIRC P Dropped 1 3/4" ball and pumped down to seat, 3 bpm at 575 psi, slowed down and with ball on seat pressured up to 1,900 psi to set hanger, slacked off 10K wt then pressured up to 4,000 si to set ZXP kr. 00:30 00:45 0.25 11,725 11,725 COMPZ CASINC DHEQ P Pressure tested ZXP packer and csg to 2,500 psi for 5 min, good test. NOTE: top of ZXP packer set at 7,820 with shoe at 11,725' 00:45 01:00 0.25 11,725 7,820 COMPZ CASINC OTHR P PU to 155K and running tool was released from liner, LD single of DP and blew down to drive. 01:00 03:30 2.50 7,820 50 COMPZ CASIN RUNL P POOH from 7,820' to the running tool at 50' 03:30 04:30 1.00 50 0 COMPZ CASINC PUTB P LD Baker running tool and cleared rig floor. 04:30 04:45 0.25 0 0 PROD2 DRILL SFTY P Held PJSM with crew, Baker and Sperry Sun personnel on PU and MU whi stock assembl . 04:45 08:30 3.75 0 404 PROD2 DRILL PULD P MU whipstock seal and milling assembly BHA #6 with MWD, oriented and u loaded same RIH to 404'. 08:30 09:00 0.50 404 497 PROD2 DRILL DHEQ P RIH with 1 std of DP and shallow tested MWD and had weak signal, Ian to test dee er. 09:00 10:00 1.00 497 2,725 PROD2 DRILL TRIP P RIH from 497' to 2,725'. 10:00 10:45 0.75 2,725 2,725 PROD2 DRILL DHEQ P Retested MWD, took several tries to get tool to test then ck'd out ok. NOTE: Discovered that 2 stds of hybrid pushpipe had been left out of the BHA. 10:45 12:00 1.25 2,725 221 PROD2 DRILL TRIP NP POOH from 2,725' to 221' 12:00 13:00 1.00 221 2,725 PROD2 DRILL TRIP NP MU 2 stds of hybrid pushpipe and RIH to 2,725' 13:00 15:15 2.25 2,725 6,926 PROD2 DRILL TRIP P RIH with whipstock from 2,725' to 6,925' 15:15 15:45 0.50 6,926 7,017 PROD2 DRILL OTHR P Made MADD pass over K-13 to correlate to MWD, MADD pass from 6,926' to 6,971', RIH to 7,017' ~ ~ ~ .- j ~~g~ 1~ t ~ ~ E • • Timc Log -- s - --- - __ _ i Date From To Dur S De th E De th Phase Code Sut~ ,o:Je T C O(t~ 04[07/2007 15:45 17:00 •1.25 7,017 7,820 PRUD'2 DRILL TRIP P Cont to RIH with WS from 7,01T and sat down on top of A2 sand ZXP packer at 7,820', sat down on packer prior to orientating, PU and had set WS. checked WS orientation and was set at 87 deg left of high side. Found DP to be mismarked, the decision was made to fish WS. 17:00 18:15 1.25 7,820 7,707 PROD2 DRILL OTHR T Sheared off and dry milled lug off the top of the WS. PU wt 145K, do wt 85K, rot wt 107K 18:15 18:30 0.25 7,707 7,707 PROD2 DRILL OWFF T Monitored well-.static, blew down top drive. 18:30 22:30 4.00 7,707 0 PROD2 DRILL TRIP T POOH from 7,707' and stood back hybrid pushpipe and MWD, LD mills, talc fill on trip out 37 bbls, actual 41 bbls. 22;30 23:00 0.50 0 297 PROD2 FISH PULD T MU whipstock retrieving hook BHA #7 &RIH to 29T. 23:00 00:00 1.00 297 2,626 PROD2 FISH TRIP T R4H with BHA #7 from 29T to 2,626' and tested MWD. 04/08/2007 00:00 01:00 1.00 2,626 7,630 PROD2 FISH TRIP T Cont. to RIH from 2,626' to 7,630', st wt u 140K, do wt 80K. 01:00 02:30 1.50 7,630 7,712=-; PROD2 FISH FISH T Oriented hook with MWD and RIH, tagged top of WS at 7,707, worked hook past top of WS and while orienting hook to 87L latched onto WS at 7,712', worked jars up to 60K over st wt and WS ulled free. 02:30 02:45 0.25 7,712 7,712 PROD2 FISH OTHR T Monitored well-static, blew down top .drive. 02:45 06:15 3.50 7,712 297 PROD2 FISH TRIP T POOH from 7,712' to BHA #8 at 279'. 06:15 07:30 1.25 297 0 PROD2 FISH PULD T POOH and stood back hybrid pushpipe and MWD, LD retrieving hook and whipstock sf+de, PU and ins ected seals and ck'd ok. 07:30 09:15 1.75 0 403 PROD2 DRILL PULD T MU new whipstock BHA #8 with MWD and oriented same, RIH to 403' and shallow tested MWD and ck'd ok. 09:15 15:00 5.75 403 7,707 PROD2 DRILL TRIP T RIH with WS from 403' to 7,770', made MADD pass thru K-13 from 6,925' to 6,965' while RIH. st wt up 140K, do wt 84K, oriented WS and RIH tagging up on A2 ZXP packer at 7,820', set WS to 12 deg left of high side with top of WS at 7,707. 15:00 16:00 1.00 7,707 7,707 PROD2 DRILL CIRC P Displaced hole over from 8.4 ppg SFMOBM to 8.4 MOBM 16:00 16:30 0.50 7,707 7,707 PROD2 DRILL DHEQ P Tested anchor seals in top of the ZXP packer to 1,000 psi for 10 min and tested ok. _- ; ~~. ~ ~ ~.. Tirne Logs - --- - -- (]d+c From To Dur S D ~u~ E Depth Pnase Cade SuFc~~ie T CO~n 04/08/2007 16:30 00_:00 7.50 7,707 7,726 PROD2 DRILL MILL P Milled window in "B" sand lateral from 7,707 to 7,720', cont to milt to 7,726', milled at 2-4K WOM, 100 rpm's, 260 gpm at 2,100 psi, off btm torque 4K, on btm 4-8K, rot wt 104K, up wt 140K, do wt 84K. 04/09/2007 00:00 00:15 0.25 7,726 7,735. PROD2 DRILL MILL P Fin. milling window in "B" lateral from 7,726' to 7,735' MD/3,702' TVD. 6' of gauge hole and 9' of under gauge hole out of window. 00:15 01:00 0.75 7,735 7,735 PROD2 DRILL CIRC P Circ hole clean while working mills thru the window, circ at 280 gpm, 2,270 psi, 100 rpm's with 5K ft-Ibs torque, rot wt 98K, up wt 135K, do wt 82K. 01:00 01:15 0.25 7,735 7,658 PROD2 DRILL OTHR P Took SPR's theh stood back 1 std of DP, blew down-top drive. 01:15 02:00. 0.75 7,658 7,658 PROD2 DRILL LOT P RU and performed a LOT on "B" lat window to 13.0 ppg EMW, 880 psi, 3,699' TVD with 8.4 - MOBM. 02:00 04:45 2.75 7,658 4,397 PROD2 DRILL TRIP P POOH from 7,658' to 6,539', POOH 21 stds to 4,397 removing 63 supersliders w/POOH. cleared rig floor. 04:~5 06:30 1.75 4,397 297 PROD2 DRILL TRIP P Cont to POOH from 4,397 to BHA #8 at 29T. 06:30 08:15 1.75 297 0 PROD2 DRILL PULD P POOH standing back hybrid pushpipe, LD bumper sub, downloaded MWD and LD milling assembly, upper mill was in au e, cleared ri floor. 08:15 08:30 0.25 0 0 PROD2 DRILL PULD P Pulled wear bushing 08:30 09:15 0.75 0 0 PROD2 DRILL OTHR P MU stack washer and flushed out same, blew down top drive, choke and kill lines. 09:15 10:45 1.50 0 0 PROD2 RIGMN SVRG P Held PJSM then slip and cut 72' of drl line then serviced the to drive. 10:45 15:00 4.25 0 0 PROD2 WELCT BOPE P RU and tested BOPE, tested rams, manifold and valves to 250 psi low and 3,000 psi high, including annular, tested rams and annular with both 4" and 4 1/2" testjts, tested Koomey, init. press. 3,000 psi, after functioning, 1,600 psi, took 35 seconds to gain 200 psi, 3 min 29 sec. for full recovery, 5 nitrogen bottles ave. 2,150 psi. Note: Jeff Jones with AOGCC waived witnessin of the test. 15:00 15:30 0.50 0 0 PROD2 DRILL PULD P Installed wear bushing and cleared rig floor 15:30 15:45 0.25 0 0 PROD2 DRILL SFTY P Held PJSM with. rig crew and Sperry Sun on PU and MU of the BHA. 15:45 18:00 2.25 0 369 PROD2 DRILL PULD NP MU 6 3/4" BHA #9 RIH to 369', MU Hycalog concretion bit on 5" motor with 1.5 deg. bend, MU MWD and oriented and uploaded same, RIH with NMFDC's and HWDP and 'ars. ~~ - ~ ~ -- L~__ ~ -- _ _. _____~ _ :.._._..._ r ._ _ _ _~_.___ % 1J-105 'A' Sand Liner Detail well: - 1J-105 ~pl'~U~~J~~#~~I~S 4-1/2" Slotted and Blank Liner Date: 4/6/2003 Alaska; fnc. - Rig: Doyon 141 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 7806.58 -:i~:: :: _ . :. ;:..-: ,. _~ ... , ,-.... :.:;:::::>~ ..::::.. 7806.58 7806.58 7806.58 7806.58 _. : 7806.58 4" DP to Surface =_> 7806.58 XO 3 1/2 LF x 4" HT 39 1.93 7806.58 Baker Liner setting tool( Does not stay in-hole) 11.46 7808.51 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 19.02 7819.97 "RS" Paekoff Seal Nipple, 6.07" OD / 4.87" ID 2.85 7838.99 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/ 4.85" FD 9.79 7841.84 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 19.60 7851.63 XO Sub 5.5"Hyd 563 X 4.5",.BTC 5.99"OD X 3.94" ID 1.44 7871.23 4 1/2" Pup Jt, 12.6 ppf, L-80 w/TR 3.80 7872.67 Jts 67 to 89 23 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 986.82 7876.47 Jts 66 to 66 1 Jts 4-1/2" BTC 11.6 .ppf, L-80 Slotted Casing w/ TR 43.31 8863.29 Jts 65 to 65 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 42.45 8906.60 Jts 64 to 64 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.35 8949.05 Jts 62 to 63 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 86.95 8992.40 Jts 61 to 61 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 42.80 9079.35 Jts 6o to 60 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 43.62 9122.15 Jts 59 to 59 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.65 9165.77 Jts 58 to 58 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 42.82 9209.42 Jtsb7 to 57 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.18 9252.24 Jts 56 to 56 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 42.71 9295.42 Jts 55 to 55 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 41.86 9338.13 Jts 54 to 54 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 43.31 9379.99 Jts 52 to 53 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w! TR 86.47 9423.30 Jts 51 to 51 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 43.13 9509.77 Jts 50 to 50 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.47 9552.90 Jts 49 to 49 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 43.29 9596.37 Jts 48 to 48 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.04 9639.66 Jts 47 to 47 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.01 9682.70 Jts 46 to 46 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.64 9725.71 Jts 39 to 45 7 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 299.10 9769.35 Jts 3s to 38 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.53 10068.45 Jts 37 to 37 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.26 .10111.98 Ran total of 5 9 jts Blank and 31 jts Slotted, Slots are 0.125"wide x 2.5"-long x 32 slo/ft. w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, 3" Centers Up Wt 195K staggered 18 deg., 3 ft. non-slotted ends. NO Constrictors ran. Dn Wt 65K Run torque rinks in the top 41 jts (# 49 thru # 89) BlockVl/t 35K Ran shoe joint slick. Torqued liner w/o torque rings to 4500 ft-Ibs, w/ torque rings to 8000 ft/Ibs Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 36 to 36 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.44 10155.24 Jts 35 to 35 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.22 10198.68 Jts 34 to 34 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.34 10241.90 Jts 33 to 33 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.86 10285..24 Jts 32 to 32 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.38 10328.10 Jts 31 to 31 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.83 10371.49 Jts 3o to 30 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.35 10414.32 Jts 29 to 29 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.90 10457.67 Jts 28 to 28 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.50 10500.57 Jts 27 to 27 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.32 10544.07 Jts 26 to 26 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.64 10587.39 Jts 25 to 25 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.62 10631.03 Jts 24 to 24 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.99 10674.65 Jts 23 to 23 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 40.00 10717.64 Jts 21 to 22 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing so.2o , 10757.64 Jts 20 to 20 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing "(Blanks) 42.85 .10837.84 Jts 19 to 19 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.04 10880.69 Jts 18 to 18 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.54 10923.73 Jts 17 to 17 1 Jts 4-112" BTC 11.6 ppf, L-80 Slotted Casing 43.51 10966.27 Jts 1& to 16 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.44 11009.78 Jts 15 to 15 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.24 11053.22 Jts 14 to 14 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 38.15 11096.46 Jts 13 to 13 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.38 11134.61 Jts 42 to 12 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing '(Blanks) 42.90 11177.99 Jts 11 to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.40 11220.89 Jts 10 to 10 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.94 11264.29 Jts 9 to s 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.29 11307.23 Jts s to s 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 40.10 11350.52 Jts 7 to 7 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 38:38 11390.62 Jts 6 to 6 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 37.35 11429.00 Jts 5 to 5 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.24 11466.35 Jts 4 to 4 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.35 11509.59 Jts 3 to 3 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.21 11552.94 Jts 2 to 2 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.89 11596.15 Jts 1 to 1 1 Jts 4-1/2" BTC 11.6. ppf, L-80 Slotted Casing 42.52 11639.04 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blank shoe joint) 41.76 11681.56 41/2" Silver Bullet Shoe 1.68 11723.32 BOTTOM OF SHOE __> 11725.00 Remarks: Total = 89 Ezee-Glider 4.5" X 5.75", 89 Stop rings Ran 1Ezee-Glider per joint floating under a stop ring installed in the middle of each joint. Liner weight including hanger 75K up, 60K down. Re: Request to pre produce new West Sak tri~ral injector 1J-105... ~ s Subject:R,~e~Request to pre produce new West Sak tri-lateral inject~~r ,Z~-028, i~'~~~p"z..,.;~ ~-~ From: Thomas Maunder <tommaunder@admin.state.ak.us> Date: Mon, 07 May 2007 14:9:11 -0800 To: NSK Prohlcili ti~'cll Supv -~~n1617{a~conocophillips.com=~ CC: James Re~~~ `_limre~~(u'admin.state.ak.us: 1J-lO5PTD #'s ~-027. Perry, I forgot to mention in the earlier message, all the permit numbers should be 207 rather than 206. Tom Thomas Maunder wrote, On 5/7/2007 12:11 PM: Perry, The intent to pre-produce this well was described in the permit to drill. Sundries should be submitted to convert from producer to injector near the end of the production period. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Weli Supv wrote, On 5/7/2007 9:54 AM: Tom, New West Sak injector 1 J-105 PTD #'s 206-027, 206-028, 206-029 is being prepared fora 30 day pre-production period to start later this week. CPAI would like to pre-produce 1 J-105 via gas lift through the open sliding sleeve above the packer, intentional T X IA communication, and delay the tubing pressure test until after the pre-production period has ended. This plan is similar to previously approved pre-production plans for 1J-118, and 1J-160. The completion has a packer at 7296' with a sliding sleeve (CMD) at 6685' and gas lift mandrels at 2262' and 6387'. A gas lift valve will be installed in the station at 2262, a dummy will be left in the station at 6387' and the sleeve will be left open as the bottom lifting point. With the sleeve open there will be T x IA communication . The annulus (IA) will not be isolated from produced fluids per 20 AAC 25.200(d) while on pre-production. Gaslift will be injected down the IA preventing production fluids from entering the IA. Both surface and intermediate casing strings were tested to 3000 psi for 30 minutes prior to drilling ahead on 3/25/07 and 4/2/07 respectively. Rig testing has demonstrated sufficient integrity to prevent uncontrolled releases. The packer was tested to 2500 psi for 30 minutes on 4/28/07 just prior to running the completion. The tubing was not tested on the rig as the sleeve was run in the open position. Coiled tubing is required to shift the sleeve due to well bore deviation. The tubing will be tested when the sleeve is closed at the end of the pre-production period and again during the state witnessed MITIA once injection has stabilized. Please confirm it is acceptable to proceed as described above. Sincerely Perry Klein Problem Well Supervisor 1 of 2 5/7/2007 3:17 PM Re: Request to pre produce new West Sak tri-lateral injector 1J-105... r . ~ r office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617 _conocophillips.com 2 of 2 5/7/2007 3:17 PM ~~'~- it t. SChlum6~r~g~~ ~PF~ '~ ~, 20~?~~ s ~,~?~ct~tt'a~t. Schlumberger-DCS '~ ,e~~~ll~"t ~''~~~~~~~ 2525 Gambell Street, Suite 400 ~~tM~~ Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL Kuparuk Color CD 04/20/07 1A-10 11638846 INJECTION PROFILE 04105/07 1 2L-3.13 11628996 LDL 04/08/07 1 1D-137 11628997 INJECTION PROFILE 04/09!07 1 2N-311A N/A USIT 04106107 1 2N-337B 11638852 SCMT 04111/07 1 1J-184 11638853 SBHP 04112!07 1 1 H-10 11638844 GLS 03/20/07 1 2W-03 11649957 MEM LDLIPPROF 04110107 1 1E-112 11638856 INJECTION PROFILE 04114/07 1 1J-156 11638857 INJECTION PROFILE 04H5I07 1 1J-127 11638859 INJECTION PROFILE 04117107 1 1J-105 11628994 USIT 04106/07 1 1J-164 • 11638858 INJECTION PROFILE 04/16/07 1 1J-164 + 11638860 INJECTION PROFILE 04/17107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • l3 From: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> To: "Thomas Maunder" <tom_maunder@admin.state.ak.us>; "Reilly, Patrick J" <Patrick.J. Reilly@conocophillips.com> Cc: "Smyth, Robin J." <Robin.J.Smythrj@conocophillips.com> Sent: Wednesday, April 11, 2007 2:23 PM Subject: RE: 1J-105 Intermediate Cement Page 1 of 2 Tom, Thanks for the input.... We can discuss later if we need to look at WFL 's {Waterflow logs) between the B and D laterals to check for channeling. I agree that the likelihood is slim based on the USIT log and past experience. Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Ce11:240-5696 ATO-1512 guy.l.schwartz@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, April 11, 2007 1:05 PM To: Reilly, Patrick J Cc: Smyth, Robin J.; Schwartz, Guy L Subject: Re: 1J-105 Intermediate Cement Pat and Robin, Just to close the loop. We did meet yesterday and examine the USIT log for this well. Although not a stellar presentation, there is likely sufficient isolation to prevent cross flow between the sands and above the zone. As I noted previously, some sort of follow-on surveillance log might be needed but that is something we need to discuss further. Since you mentioned that Guy had looked at the log, I also copied him on this response. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 4/10/2007 7:54 AM: Pat and Robin, This morning is booked. Early afternoon looks better. I took a look at the log. Not too encouraging, however there have been others not too different. I suspect there will be some need of temperature logs or some other method to demonstrate that there is isolation. You all might check and see what has been done on the "other" wells. I don't specifically have them in mind right now. One other thing I am curious, more in the operations area for Pat, are there models or projections done for what the weight indicator should show during cementing. With all the changing fluid weights, I would suspect that the hook weight goes up as the heavier slurry travels down the casing and then begins to change as the different fluids rise in the annulus. When you displace, the lighter mud is replacing the heavier ~~~~ 6/14/2007 Page 2 of 2 cement bringing another variable into the mix. Loosing all down weight certainly could be alarming, but it might also really be what the physics (inside and outside fluid weights, drag, etc) of the situation are. Just a thought. Look forward to catching up with you both. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 4/9/2007 4:53 PM: Guys, I will get back to you tomorrow morning. Is there a summary available of the cementing operations including the rig reports? Tom Reilly, Patrick J wrote, On 4/9!2007 4:46 PM: Tom, Robin and I would like to discuss the 1J-105 bond log with you. Would you be available sometime tomorrow afternoon? We can discuss over the phone or if you prefer, we can visit at your office and bring a hard copy of the log. «USI Cement 035.PDS» Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J_.Re_illytc~'~i conocophillips.com __ «Patrick.J.Reilly a~?conocophillips.co__m._v_cf» 6/14/2007 Re: 1J-105 PB1 Intermediate Hole Sidetrack Subject: Re: 1J-105 PB1 Intermediate Hole Sidetrack From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tl~u, 29 Mar 2007 10:22:06 -0800 ~ (~'~ - ~ ~ ~~ ~Co: "Reilly, f'aU~ick.1" ~~f'atl~ick..1.Reilly~~;conoec~phillips.com--~ ~----- CC: "Roh~rts, L3~~~~~~n h~~~ :Fluwen.~~.IZ.oberts~u!conocophillii~s.com~ Pat, That is good news that only a portion of 1 of the intervals had been cut. It sounds like you all are sensitive to what interval(s) had been penetrated. Although the A, B and D intervals are all in the defined WS pool, from a reservoir management perspective separation of the intervals is desirable. Providing isolation above the pool is also important since this is an injection well. Given the planned profiles of the wells at 1 J, there is probably not a lot of tvd involved with PB 1. Cementing the casing as planned should isolate the PBl section. For future reference and discussion with your associates, had more than 1 interval of the WS been penetrated it is probable that a cement plug would have been needed. If such a situation develops, contact should be made with the Commission as soon as practical. Good luck with the remaining hole section. Call or message with any questions. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 3/29/2007 10:09 AM: Tom, The PB1 section from 7,071' - 7,473' was already in the K13 and also cut some of the West Sak D. The top of the West Sak C had not been reached. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907} 244-5558 CELLULAR (907) 265-1535 FAX Patrick,J.Reilly(t~conocophillips.com From: Thomas Maunder [mailto;torn maunder~admin.state.ak.us] Sent: Thursday, March 29, 2007 10:01 AM To: Reilly, Patrick J Cc: Roberts, Bowen E Subject: Re: 1J-105 PB1 Intermediate Hole Sidetrack Mike, Bummer. What formations did the PB 1 hole section cut? Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 3/29/2007 9:50 AM: 1 of 2 3/29/2007 10:29 AM Re: 1J-105 PB1 Intermediate Hole Sidetrack Tom, The details of the sidetrack are as follows: Well: 1J-105 Rig: Doyon 141 Date: 3/28/07 Time: 1530 hrs Last Casing: 3,387 MD of abandoned section: 7,071' - 7,473' While drilling the intermediate section the motor parted. We sidetracked to the low side and to the right. We are planning to isolate the sidetrack by cementing the intermediate casing. The cement will cover the abandoned section sidetrack point. If you need any additional information please contact me. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J,Reillyconocophillips.com «Patrick.J.Reilly{~ccnocophillips.com.vcf» 2 of 2 3/29/2007 10:29 AM ~e 7~~TT ~y l~t~ u ~ 333 W. 7th AVENUE, SUITE 100 ~s •'Y~~3~iS®i~ ~ ~"~-7i®li ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105 ConocoPhillips Alaska, Inc. Permit No: 207-027 Surface Location: 2186' FSL, 2432' FEL, SEC. 35, T 11 N, R l OE, UM Bottomhole Location: 2511' FNL, 2139' FWL, SEC. 1, TlON, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this~day of March, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post tJfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com February 26, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RE~EIVEt? FEB 2 ~ 2007 Alaska Oil & Gas Cons. Commission Anchorage Re: Applications for Permit to Drill, West Sak Injector, 1J-105, 1J-105 Li, iJ-105 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injection well, a trilateral horizontal well in the West Sak ~~A2", ~~B"and °D" sands. The main bore of the well will be designated 1J- 105, and the lateral bores of the well will be designated 1J-105L1 and iJ-105L2. 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-105 is March 19, 2007. ~ 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 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~{~~~ EEC 2 8 "lUut ~iaska Oil & bas Cons. Cafnmissian Anchorage 1a. Type of Work: 1 b. Curcent Well Class: Exploratory ^ Development Oil ^ 1 c. Specify if well is proposed for: Drill Q 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-105 3. Address: 8. Proposed Depth: / 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11724' TVD: 3798' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2186' FSL, 2432' FEL, Sec. 35, T11 N, R10E, UM ~ ADL 25661 & 25662 ~ West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 693' FSL, 1987' FWL, Sec. 36, T11 N, R10E, UM ALK 471 & 2177 3/19/2007 Total Depth: 9. Acres in Property: 14. Distance to 2511' FNL, 2139' FWL, Sec. 1, T10N, R10E, UM ~ 2560 Nearest Property: > 2 miles ~ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation /O ~ A/g ~,. ~ 5. Distance to Nearest ' ' Surface: x- 558776 y- 5945998 Zone- 4 (Height above GL): 28' RKB feet @ 7x68 Well within Pool: 1 J-14 , 240 16. Deviated wells: Kickoff depth: 250 ft. ~ 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) Maximum Hole Angle: 93.4° deg Downhole: 1732 psig - Surface: 1309 psig ' 18. Casing Program cif c S ti Setting Depth Quantity of Cement Size i pe a ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3265' 28' 28' 3293' ~ 2250' ~ 570 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8487 28' 28' 8515' 3850' 500 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 4184' 7540' ' 3745' " 11724' ~ 3798' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Stru ctu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 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 ~,~~$ 3~ Date Z.~'L(o~b7 Pre h n All u k Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: /~~7"©Z-~ 50- ~ 2.~^ Z3 ~ ~ "UrJ Date: '!j • ~GJ . O 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 [/]'~ M\"'~~. ~ct~,r~~ C W,,~~~- ` ~ ~ Other: ~r c ~ ~ 2S measures: Yes ^ No [1 ~ ctional svy req'd: Yes [~ No ^ 3_s_o~- ROVED BY THE COMMISSION ' J ,COMMISSIONER DATE: Form 10-401 Revised 12/2005 ~ /~a~~i ~ Submit in Duplicate ~ation for Permit to Drill, Well 1J-105 Revision No.0 Saved: 23-Feb-07 Permit It -West Sak Well #1J-105 •~~~~ Application for Permit to Drill Document a~ ~'~ ~~ fIt~W~ll M~ x i m i x e V~ell ~alpe Table of Contents 1. Well Narne ............................................................................................... .. . 2 .... ............ Re uirements of 20 AAC 25.005 ............................................. 2 p (~ .......................................................... 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) .........................................•-•--•--..............,.....:...-•-•--.................... 2 Requirements of 20 AAC 25.050(b) ..................................,..........................................-•----.................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c) (3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25..005 (c)(4) ...........................••~-•----..................--~--......,............,................... 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cemen#ing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................ ............. .... 4 Requirements of 20 AAC 25.005(c)(8) ...........................................................•-.-.---................,............... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ...................................................................:........................... 5 Lateral Mud Program (MI VersaPro Mineral Oi/ Base) A/8/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 ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11)-•----•-•• ......................................................•-••---.............---......... 6 OR161NAL 1J-105 PERMIT lT Page 1 of 8 Printed: 23-Feb-07 • ~ation for Permit to Drill, Well 1J-105 Revision No.O Saved: 23-Feb-07 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) .........................................,.....:................_............................... 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ..........................................................................:..................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................... ......... .............................. ............................. 8 . .... .. ... Attachment 1 Directional P/an ...........................................................:.:.....................::.......................... 8 Attachment 2 Drilling Hazards Summary..........: ...............................................................:...........:....... 8 Attachment 3 BOP Schematic ..........................:..............:............:......... Error! Bookmark not defined. Attachment 4 Cement Loads and CemCADE Summary ...........................:...............................:........... 8 Attachment 5 Well Schematic .............................................................................:......................:........... 8 Attachment 6 '4 Mile Radius Effect for Injector..: .........................:...........................................,............ 8 1. Weld Name Requirements of 20 AAC 25.005 (f) Each we/f must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.041/(6). For a we// with mu/tip/e wet/ branches, each branch must simi/ar/y be identified by a unique name andAPl number by adding a suffix to the name designated for the well by the operator and to the number assigned to the we/I by the commission. The well for which this Application is submitted will be designated as 1J-105. 2. .Location Summary. Requirements of 20 AAC 25.005(c)(2) An app/icatian 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 identifed in the app/ication: (2) a p/at identifying the property and the property`s owners and showing (A)the coordinates of the proposed location of the we/l at the sun`ace, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed focation of the we// at the surface, referenced to the state plane coordr"Hate system for this state as maintar"ned by the Nationa! Geodetic Survey in the National Oceanic and Atmospheric Administration; (CJ the proposed depth of the we!/ at the top of each objective formation and at tote/depth; 9 ~.f37_' ~F L Location at Surface 2187' FSL &43-24' FEL -Sec 35 - Ti1N - R10E ASP Zone 4 NAD 27 Coordinates RKB Elevat%On 109' AM SL Northings; 5,945,998 Eastings• 558,776 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak "A2" Sand 693' FSL & 1987 FWL -Sec 36 - T11N - R10E .ASP Zone 4 NAD 27 Coordinates MeaSUref/ De th, RKB: 8,515 Northings.• 5,944,541 Eastings; 563,207 Tote/ l/eitica/De th, RKB: 3,850 Tote/ l/ertica/ De th, SS.• 3,740 Location at Total De th 2511' FNL & 2139' FWL -Sec 1 - T10N - R10E ASP Zone 4 NAD 27 Coordinates MeaSUred De th, RKB: 11, 724 Northings: 5,941,339 Eastings• 563,388 Tote/ ~ertica/De th, RKB,• 3 798 Tote/ l/ertical De th SS.• 3,689 OR!61NAL i 1J-105 PERMIT IT Page 2 of 8 Printed: 23-Feb-07 • ~tion for Permit to Drill, Well 1J-105 Revision No.O Saved: 23-Feb-07 and (D) other information required by 20 ARC 25.050(6); Requirements of 20 AAC 25.050(6) If a we/I is to be intentions//y deviated, the application for a Permit to Drifl (Form 10-401) must (1) ine/ude a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including af/ adjacent wellbares within 2tJ[7 feet of any portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wel/bore (A) list the names of the operators of those we//s, to the extent that those dames are kna~rn ar discoverable in public records, and show that each named operator has /assn furnished a copy of the application by certitled mar"l; or (B) state that the applicant is the on/y affected awner. The Applicant is the only affected owner. 3. Blowout Prevention ~quipmelnt Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Ori/l must be accompanied by each of the fo/lawing items, .except for an item already on d/e with the commission and identified in the application; (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 2~ 035, 20 AAC 25.036, or 20 RAC 25, 037, as apply"cab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well"1J-105.- For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) Rn app/icatioh for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication; (4) information on drilling hazards, including (A) the maximurrr downho% pressure that maybe encountered, criteria used to determine it, and maximum potentia/surface pressure based on a methane gradient; j The expected reservoir pressures in the West Sak sands in the iJ area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential. surface pressure (MPSP) based on the above maximum .pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,309 psi, calculated:. MPSP =(3,.849 ft TVD)(0.45 - 0.11 psi/ft) =1,309 psi ' (B) data on potential gas zones; i The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia/ causes of ho% problems such as abnorma//y gea pressured strata, lost circa/ation zones, :and zones that have a propensity for differential sticking,• 1J-105 PERMIT IT Page 3 of 8 Printed: 23-Feb-07 Please see Attachment 2: 1J-105 Drilling Hazards Summary. ~tion for Permit to Drill, Well 1 J-105 Revision No.O Saved: 23-Feb-07 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Drill must be accompanied 6y each of the following items, except for an item afready on dle with the commission and identified in the application; (S) a description of the procedure for conducting farmat/on integrity tests, as required under 20 AAC 25. tJ30(f); iJ-105 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission.. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dri// must ve accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application; (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated /finer, ar screen to be installed; Casing and Cementing Program I See also Attachment 3' £ement Summary ~- \~ S Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 3,265 28 / 28 3,293 /2,250 570 sx ASLite Lead, drift 18fl sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 8,487 28 / 28 8,515 / 3,850 4,447. MD / 2,711' TVD. Cemented w/ 500 sx Dee CRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC. CSG 4,184 7,540 / 3,745 11,724 / 3,798 Slotted- no cement Slotted Lateral 1J- 4-1/2 6-3/4" B Sand 11.6 L-80 BTC CSG 4,125 7, , o ed- no cement Slotted Lateral (1J-105 Ll) 4-1/2 6-3/4" D Sand 11.6 L-80 BTC CSG 4,429 7,092/ 3,662 11,521 / 3,562 Slotted- no cement slotted Lateral (1J-105 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Dri/! must be accompanied by each of the fo/%wing items, except for an item a{ready. on file with the commission and r"dentified in the application; (7) a diagram and description of the diverter system as required 6y 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25, 035(h)(Z); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-105. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application far a Permit to Drr`l1 must be accompanied by each of the fa!locving items, except for an item already on file with the commission and identified in the app/ication; (8) a drilling t7uid program, including a dr"agram and descriptr"on of the drilling fluid system, as required by 2f) AAC Z5, 033; Drilling will be done with muds having the following properties over the listed intervals: 1J-105 PERMIT IT Page 4 of 8 Printed: 23-Feb-07 ~~~~t~~L Surface Hole Mud Program (extended bentonite) ~tion for Permit to Drill, Well 1J-105 `~ Revision No.0 Saved: 23-Feb-07 Spud to Base of Permafrost Base of Permafrost to 10 3/4" Casin Point Initial Value Final Value Initial Value Final Value Density (pPg) $.9 9.2 9.5 9.6 Funnel Viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 cP Plastic Viscosity 20 45 15 20 lb/100 s pH 8.5 9.0 8.5 9.0 API Filtrate cc / 30 min NC 8.0 *9.6 ppg if hydrates are encountered ~ Intermediate Hole Mud Program (LSND) 10-3/4"Cs Shoe to 7-5/8" Cs Point Value Density (ppg). 9.0 - 9.1 Funnel Viscosity 45 - 60 (seconds Plastic Viscosity Ib/100 s 12 - 18 Yield Point (cP) 26 - 35 API Filtrate (cc / 30 min)) 4 - 6 Chlorides (mg/I) <500 p1-1 9.0 - 9.5 MBT <20.0 5.0 7.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) AIB/D sand laterals Value Density pp 8.6 Plastic Viscosity 15 - 25 (lb/100 sfJ Yield Point 18 - 28 cP) HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical. >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fr/e with the commission and identi>ted in the application: (9) for an exploratory or stratigraphic test well, atabu/atr`on setting out the depths of predicted a6norrnally geo pressured strata as required by ~0 AAC 25.033(f); Not applicable: application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) .4n application for a Permit to Drill must be accompanied by each of the fo/%wing .items, except for an item already on fle with the commission and identr`fied in the application; (1(I) for an exploratory or stratigraphic test well, a seismic refraction or reflection ana/ysis as required by 2l1 AAC 25.Ob1(a), Not applicable: Application is not for an exploratory or stratigraphic test well 1J-105 PERMIT IT Page 5 of 8 Printed: 23-Feb-07 ~~~~... ~ation for Perrnit to Drill, Well 1J-105 Revision No.O Saved: 23-Feb-07 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fs~r a Permit to Drill must be accompanied by each of the fo!/owing items, except for an iterrt already an file with the commission and identified in the applicati©n,° (I Z) far a well drilled fram an offshore platform, mabi/e bottorra-founded structure, jack-up rr`g, ar flaating drilfing vessel,. air analysis: ofseabed conditions as required by 20AAC'25.061(b); Not applicable: Application is not for an offshore well 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An apply"cation far a Permit to Dril/ must be accompanied by each of the following items, except for an item a/ready on-file with the commission and identified in the app/ication: (12) evidence showing that the requirements af2!? AAC 25. ©25 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fallowing items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. <f 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4"Annular with 16" diverter line and functiontesta 3. .Spud and directionally drill 13-1/2" hole to casing point at +/- 3,293' MD / 2,250' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement withmud and,- pressure test casing to .2500 psi for 30 minutes and record results. Perform top job. if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above. and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 his before test. 6. PU 9-7/8" bit and 6-1/4" driAing assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment.. Re-test casing if cement is tagged more than 100 feet above the float collar.. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 8,515 MD / 3,850' TVD, the prognosed top of the A2 sand.. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 4,447 MD / 2,711' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results.. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel ~' 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be .less than 12.0 ppg)• 14. Directionally drill 6-3/4" hole to TD at +/- 11,724' MD / 3,798' TVD as per directional plan. 1J-105 PERMIT IT Page 6 of 8 • Printed: 23-Feb-07 • ~tion for Permit to Drill, Well 1J-105 Revision No.0 Saved: 23-Feb-07 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace. to solids-free oil based mud. POOH on elevators. 16. Run USIT log for cement bond. ~ + ~` `? p ~~~ ~"'~-~ 17. PU and run 4-1/2" slotted liner. i 18. Land liner, set liner hanger @ +/- 7,540' MD / 3,745' TVD. POOH. Note: Remaining operations are covered under the 1J-105L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 7,440 MD / 3,728' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH.. 22. Drill to TD of B sand lateral at 11,565' MD / 3,634' TVD, as per directionaF plan. 23. POOH, -back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger.. 27. Release hanger running tool. POOH. 28. Makeup junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the iJ-105L2 Application for Permit to Drill, and are provided here for information only. 29. Run and. set Baker WindowMaster whipstock system, at window point of 7,092' MD / 3,662' TVD, the top of the D sand. 30. Mill 6-3/4" window. POOH. 31. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 11,521' MD / 3,562' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. POOH. 38. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 39. POOH, laying down drill pipe as required. 40. PU completion as required and RIH to depth. Land tubing. Set BPV. 41. Nipple down BOPS, nipple up tree and test. Pull. BPV. na~rIN.AL 1J-105 PERMIT IT Page 7 of 8 Printed: 23-Feb-07 tion for Permit to Drill, Well 1J-105 Revision No.0 Saved: 23-Feb-07 42. Freeze protect well with diesel 43. Set BPV and move rig off. 44. Rig up wire line unit. Pull BPV. 45. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 46. Rig up wireline: Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and. Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for- a Permit to flriil must be accompanied 6y each of the fol%wing ifems, except for an item already on fiie with the commission and identified in the application: (14) a genera/ description ofhoEV the operator plans to dispose of dri/ting rraud artd cuttings and a statement of whether. the operator intends to request authorization under 20 AAC 25.180 for an annufar disposal operation in t/~e wel/.; Waste fluids generated during the drilling process will be disposed of either by pumping atathorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved. disposal well, or stored, tested for hazardous substances, and, (if free of hazardous substances) used on pads. and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of thiswell for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary. Attachment 4 Well Schematic Attachment 5 % Mile Radius Effect for Injector ORIGINAL 1J-105 PERMIT IT Page 8 of 8 Printed: 23-Feb-07 • • ConocoPhillips Alaska Plan: 1 J-105 (wp04) Sperry Drilling Services Proposal Report -Geographic 23 February, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-105 1J-105 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-105 Plan RK8 @ 109.OOft (Doyon 141 (28+81)) N True ~ API - US Survey Feet 1 .= _r^ s-,, .~., ~~ . ~~.~:.=ate Sperry Qriliing Services ORIGINAL ~~ HALL IBUATON ~ \vrt.Lnr_Tn1LS Plano-los (;round Level: 81.00 Sperry ~riliing Services +N/-S IL \~' Norihin Fasting Latittude Longitude Slot 000 0.00 59.!1998.64 518776.16 70°IS'47.036N 149°31'29.39W Project: Kuparuk River Unit Site: Kuparuk 1J Pad zooo- Well: Plan 1J-105 10 3/4" Casing ~ 3294' MD, 2250' TVD. 2066' PEL., 783' PEL - Scc35-'f l I N-RIOIr. WeIlbOre: 1 J-105 _ Plan: 1 J-105 (wp04) 1500 O j I ^, I I SHL 2187 FSL, 2432'FEL-Sec35•TIIN-RlOE ~~ o O 1000 ' ~ i ~~ ~ ~~ t i ~ °o r ~ 500 ~ 15pU ~ ~~ r 'ro / J ~ t O ,~ i r0 O 250 _ _ _ _ _ - _ I1-105 D Top 01; 09 07 - - - - - - - IJ-105 B Top (wp04) -500 }750 -1000 I1 I O~~pO C -1500 7 5/8" Casing @ 8515' MD, 3850' TVD: 693' FS4 I98T FWL - Sec36-TI IN-RI OE _ _ _ _ _ _ '' _ _ ~ t - ~: 0 s -2000 C 0 z o -2500 - U-105 MB ACP301090 - 3000 - ------- IJ-105 \fB AC'P-0OI p00 -3500- ___----- IJ-105 MB .4 CP501/07D~ -4000 -4500 - ~ 4 1/2" - BHLtCil11724'MD, 3798'TVD: 2511'PNL,?139'FWL-Scc01=PION-RIOG- ----- ----- -------I1-10±AToe 010(1 t --- CASING DETAILS t Plan IJ-105/I1-105 (wp04) -5000 No MD PVD TVDss Natne Sizc T 1 3293.57 2250.00 2141.00 10 3/4" 10-;/4 2 8515.05 3849.65740.649782 7 S/8" 7-S/8 11724.06 3798.00688.999782 4 1/2" 4-I2 M Azimuths to True North Magnetic North: 24.65° -5500-- Magnetic Field Strength: 57552.5nT _ Dip Angle: 60.75° - Date: 11/18/2004 Model: BGGM2005 6000 - , , ~ I -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 annn avtn 6000 s' west(-)/East(+) (900 tt/in) ConocoPhillips l~laska ORIGINAL Hailiburton Company C4P10C©~~'11~~a~'?~5 Planning Report -Geographic Sperry Drilling Services Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska, Inc. ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk RiverUnit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature ~ Wellbore: 1J-105 Design: 1J-105 (wp04) -- - -- Project Kuparuk. Fiver Unit. North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level r Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-105 Well Position +N/-S 0.00 ft Northing: 5,945,998.64ft Latitude: 70° 15' 47.036" N +E/-W 0.00 ft Easting: 558,776.16 ft Longitude: 149° 31' 29.390" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-105 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 11/18/2004 24.65 80.75 57,553 ~~ ~n ~ s_s ~ ,, -- Design 1.1-1 u5~wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 180.00 2/23/2007 10:18:59AM Page 2 of 9 COMPASS 2003.11 Build 48 'fl`y ~~ ~ ~~` ~ ~ ~ ~ . Hatliburton Company L,~l~~-~~~t ~~~~~~~~~~~~~ Planning Report -Geographic Alaska Sp®rry Drilling Service Database: .Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81 )) Site: i r~~_,_~ruk 1J Pad North Reference: True Well: I'Ian 1J-105 Survey Calculation Method; Minimum Curvature Wellbore: 1 J-105 Design; 1J-105 (wp04) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (~) ~o) (a~ ~~) ~~) (ft) (°/100ft1 (°l100ft1 (°l100ft1 (~~ ', 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 278.00 0.00 0.00 278.00 0.00 0.00 0.00 0.00 0.00 0.00 702.42 10.61 40.00 700.00 30.02 25.19 2.50. 2.50 0.00 40.00 1,631.26 47.24 56.34 1,500.00 293.84 376.37 4.00 3.94 1.76 20.00 1,731.26 47.24 56.34 1,567.89 334.54 437.49 0.00 0.00 0.00 0.00 2,163.64 66.70 56.34 1,802.43 534.50 737.77 4.50 4.50 0.00 0.00 2,413.64 66.70 56.34 1,901.32 661.77 928.88 0.00 0.00 0.00 0.00 3,066.23 66.70 67.00 2,160.08 945.66 1,455.46 1.50 0.00 1.63 92.11 3,316.23 66.70 67.00 2,258.96 1,035.37 1,666.82 0.00 0.00 0.00 0.00 4,539.84 66.70 87.00 2,747.14 1,286.49 2,754.52 1.50 0.00 1.63 93.99 4,739.84 66.70 87.00 2,826.25 1,296.10 2,937.96 0.00 0.00 0.00 0.00 5,823.56 68.13 134.13 3,263.49 955.59 3,839.26 4.00 0.13 4.35 97.74 6,060.40 68.13 134.13 3,351.71 802.54 3,997.02 0.00 0.00 0.00 0.00 7,042.04 78.00 179.32 3,651.60 -36.68 4,347.15 4.50 1.01 4.60 84.74 7,092.04 78.00 179.32 3,662.00 -85.59 4,347.73 0.00 0.00 0.00 0.00 7,288.33 78.00 179.32 3,702.81 -277.57 4,350.01 0.00 0.00 0.00 0.00 7,440.73 82.55 178.92 3,728.54 -427.72 4,352.32 3.00 2.99 -0.26 -5.00 7,540.73 82.55 178.92 3,741.50 -526.86 4,354.19 0.00 0.00 0.00 0.00 7,656.60 82.67 175.42 3,756.40 -641.61 4,359.87 3.00 0.10 -3.02 -88.31 8,251.09. 82.67 175.42 3,832.24 -1,229.35 4,407.00 0.00 0.00 0.00 0.00 8,415.05 87.00 177.76 3,847.00 -1,392.31 4,416.71 3.00 2.64 1.43 28.46 8,632.03 93.43 178.79 3,846.19 -1,609.07 4,423.24 3.00 2.96 0.47 9.08 8,708.80 93.43 178.79 3,841.60 -1,685.69 4,424.87 0.00 0.00 0.00 0.00 8,797.52 91.98 177.76 3,837.41 -1,774.27 4,427.54 2.00 -1.63 -1.16 -144.66 9,822.52 91.98 177.76 3,802.00 -2,797.87 4,467.58 0.00 0.00 0.00 0.00 9,923.55 91.00 178.01 3,799.37 -2,898.80 4,471.30 1.00 -0.97 0.25 165.57 10,288.08 91.00 178.01 3,793.00 -3,263.06 4,483.95 0.00 0.00 0.00 0.00 10,464.87 90.47 176.33 3,790.73 -3,439.61 4,492.68 1.00 -0.30 -0.95 -107.58 10,922.66 90.47 176.33 3,787.00 -3,896.44 4,522.01 0.00 0.00 0.00 0.00 11,061.21 89.09 176.14 3,787.53 -4,034.68 4,531.11 1.00 -0.99 -0.14 -172.12 11,724.07 89.09 176.14 3,798.00 -4,695.96 4,575.77 0.00 0.00 0.00 0.00 2/23/2007 10:18:59AM Page 3 of 9 COMPASS 2003.11 Build 48 ORIGINAL '+~' Halliburton Company ~a~~~~1~ Ca11000P~'tl~~ip5 Planning Report -Geographic Alaska Sperry ~rHing Servic®s Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-1 Q5' ~ Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB'@109.OOff (Doyon 141 (28+81)) ~~, Project: Kuparuk River Unit MD Reference: Plan RKB. @ 109.OOft (Doyon 141 (28+81)) I Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-105 Design: 1J-105 (wp04) Planned Survey 1 J-105 (wp04) MD Inclination Azimuth TVD (ft) (') (°) (ft) 28.00 0.00 0.00 28.00 SHL: 2187 ' FSL, 2432' FEL - Sec3 5-T11 N-R10E 100.00 0.00 0.00 100.00 200.00 0.00 0.00 200.00 278.00 0.00 0.00 278.00 300.00 0.55 40.00 300.00 400.00 3.05 40.00 399.94 500.00 5.55 40.00 499.65 600.00 8.05 40.00 598.94 700.00 10.55 40.00 697.62 702.42 10.61 40.00 700.00 800.00 14.34 45.39 795.26 900.00 18.24 48.64 891.23 1,000.00 22.17 50.78 985.06 1,100.00 26.12 52.29 1,076.30 1,200.00 30.08 53.43 1,164.49 1,300.00 34.06 54.33 1,249.21 1,400.00 38.03 55.06 1,330.05 1,500.00 42.01 55.67 1,406.62 1,600.00 46.00 56.19 1,478.53 1,631.26 47.24 56.34 1,500.00 1,648.94 47.24 56.34 1,512.00 Pfrost 1,700.00 47.24 56.34 1,546.67 1,731.26 47.24 56.34 1,567.89 1,800.00 50.34 56.34 1,613.17 1,876.16 53.76 56.34 1,660.00 T3 1,900.00 54.84 56.34 1,673.91 2,000.00 59.34 56.34 1,728.24 2,100.00 63.84 56.34 1,775.81 2,163.64 66.70 56.34 1,802.43 2,200.00 66.70 56.34 1,816.81 2,300.00 66.70 56.34 1,856.37 2,400.00 66.70 56.34 1,895.92 2,413.64 66.70 56.34 1,901.32 2,500.00 66.66 57.75 1,935.51 2,561.79 66.64 58.76 1,960.00 K15 2,600.00 66.63 59.38 1,975.16 2,700.00 66.61 61.02 2,014.84 2,800.00 66.61 62.65 2,054.54 2,900.00 66.63 64.29 2,094.22 3,000.00 66.67 65.92 2,133.86 3,066.23 66.70 67.00 2,160.08 3,100.00 66.70 67.00 2,173.43 Map Map SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (ft) (ft) (ft) (ft) (°(100ft) (ft) -81.00 0.00 0.00 5,945,998.64 558,776.16 0.00 0.00 -9.00 0.00 0.00 5,945,998.64 558,776.16 0.00 0.00 91.00 0.00 0.00 5,945,998.64 558,776.16 0.00 0.00 169.00 0.00 0.00 5,945,998.64 558,776.16 0.00 0.00 191.00 0.08 0.07 5,945,998.72 558,776.23 2.50 -0.08 290.94 2.49 2.09 5,946,001.14 558,778.23 2.50 -2.49 390.65 8.23 6.91 5,946,006.92 558,783.00 2.50 -8.23 489.94 17.30 14.52 5,946,016.05 558,790.54 2.50 -17.30 588.62 29.68 24.90 5,946,028.51 558,800.83 2.50 -29.68 591.00 30.02 25.19 5,946,028.85 558,801.11 2.50 -30.02 686.26 45.39 39.57 5,946,044.34 558,815.37 4.00 -45.39 782.23 64.43 60.14 5,946,063.54 558,835.79 4.00 -64.43 876.06 86.71 86.51 5,946,086.02 558,861.98 4.00 -86.71 967.30 112.12 118.55 5,946,111.67 558,893.82 4.00 -112.12 1,055.49 140.53 156.11 5,946,140.37 558,931.16 4.00 -140.53 1,140.21 171.80 199.01 5,946,171.97 558,973.80 4.00 -171.80 1,221.05 205.79 247.03 5,946,206.33 559,021.55 4.00 -205.79 1,297.62 242.32 299.93 5,946,243.27 559,074.17 4.00 -242.32 1,369.53 281.22 357.48 5,946,282.62 559,131.40 4.00 -281.22 1,391.00 293.84 376.37 5,946,295.38 559,150.19 4.00 -293.84 1,403.00 301.03 387.17 5,946,302.66 559,160.93 0.00 -301.03 1,437.67 321.81 418.38 5,946,323.68 559,191.97 0.00 -321.81 1,458.89 334.54 437.49 5,946,336.55 559,210.98 0.00 -334.54 1,504.17 363.19 480.52 5,946,365.54 559,253.78 4.50 -363.19 1,551.00 396.48 530.50 5,946,399.21 559,303.50 4.50 -396.48 1,564.91 407.21 546.61 5,946,410.06 559,319.53 4.50 -407.21 1,619.24 453.72 616.47 5,946,457.12 559,389.01 4.50 -453.72 1,666.81 502.46 689.66 5,946,506.42 559,461.81 4.50 -502.46 1,693.43 534.50 737.77 5,946,538.83 559,509.66 4.50 -534.50 1,707.81 553.01 765.56 5,946,557.55 559,537.31 0.00 -553.01 1,747.37 603.91 842.01 5,946,609.05 559,613.34 0.00 -603.91 1,786.92 654.82 918.45 5,946,660.54 559,689.38 0.00 -654.82 1,792.32 661.77 928.88 5,946,667.57 559,699.76 0.00 -661.77 1,826.51 704.90 995.42 5,946,711.22 559,765.95 1.50 -704.90 1,851.00 734.75 1,043.66 5,946,741.44 559,813.95 1.50 -734.75 1,866. 16 752. 78 1,073 .75 5,946,759 .70 559,843 .90 1.50 -752. 78 1,905. 84 798. 39 1,153 .40 5,946,805 .93 559,923 .18 1.50 -798. 39 1,945. 54 841. 71 1,234 .31 5,946,849 .88 560,003 .74 1.50 -841. 71 1,985 .22 882. 71 1,316 .43 5,946,891 .52 560,085 .53 1.50 -882. 71 2,024 .86 921. 36 1,399 .70 5,946,930 .81 560,168 .49 1.50 -921. 36 2,051 .08 945. 66 1,455 .46 5,946,955 .53 560,224 .05 1.50 -945. 66 2,064 .43 957. 78 1,484 .01 5,946,967 .88 560,252 .50 0.00 -957. 78 2/23/2007 10:18:59AM Page 4 of 9 COMPASS 2003.11 Build 48 s ~ , ~ f) t e ! ,`.... • CU11t}CQ~'11~~1~15 Alaska Halliburton Company Planning Report -Geographic Sperry Drilling Services Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+II1)) Site: Kuparuk 1J Pad North Reference: True Wcll: Plan 1J-105 Survey Calculation Method: Minimum Curvature Wel l bore: 1 J-105 Design:. 1J-105 (wp04) Planned Survey 1J-105 (wp04) Map Map. MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) lft) (ft) (ft) lft) (ft) (°t100it) (ft) 3,200.00 66.70 67.00 2,212.99 2,103.99 993.66 1,568.55 5,947,004.42 560,336.76 0.00 -993.66 3,293.57 66.70 67.00 2,250.00 2,141.00 1,027.24 1,647.66 5,947,038.61 560,415.59 0.00 -1,027.24 10 3/4" Ca sing @ 3294' MD, 2250 ' TVD: 2066' FEL, 783' FEL - Sec35-T1 1 N-R10E -Casing Pt - 10 3/4" 3,300.00 66.70 67.00 2,252.54 2,143.54 1,029.55 1,653.10 5,947,040.96 560,421.01 0.00 -1,029.55 3,316.23 66.70 67.00 2,258.96 2,149.96 1,035.37 1,666.82 5,947,046.89 560,434.68 0.00 -1,035.37 3,400.00 66.62 68.37 2,292.15 2,183.15 1,064.58 1,737.97 5,947,076.65 560,505.60 1.50 -1,064.58 3,500.00 66.54 70.00 2,331.91 2,222.91 1,097.19 1,823.74 5,947,109.92 560,591.10 1.50 -1,097.19 3,600.00 66.47 71.63 2,371.78 2,262.78 1,127.33 1,910.35 5,947,140.73 560,677.46 1.50 -1,127.33 3,700.00 66.42 73.27 2,411.74 2,302.74 1,154.97 1,997.75 5,947,169.05 560,764.63 1.50 -1,154.97 3,800.00 66.39 74.90 2,451.76 2,342.76 1,180.09 2,085.87 5,947,194.86 560,852.55 1.50 -1,180.09 3,900.00 66.38 76.54 2,491.82 2,382.82 1,202.69 2,174.67 5,947,218.15 560,941.16 1.50 -1,202.69 4,000.00 66.38 78.18 2,531.88 2,422.88 1,222.74 2,264.06 5,947,238.89 561,030.39 1.50 -1,222.74 4,100.00 66.41 79.81 2,571.93 2,462.93 1,240.23 2,354.01 5,947,257.08 561,120.18 1.50 -1,240.23 4,200.00 66.44 81.45 2,611.93 2,502.93 1,255.15 2,444.43 5,947,272.70 561,210.48 1.50 -1,255.15 4,300.00 66.50 83.09 2,651.85 2,542.85 1,267.48 2,535.28 5,947,285.74 561,301.22 1.50 -1,267.48 4,400.00 66.57 84.72 2,691.67 2,582.67 1,277.22 2,626.49 5,947,296.20 561,392.34 1.50 -1,277.22 4,500.00 66.66 86.35 2,731.37 2,622.37 1,284.37 2,717.99 5,947,304.06 561,483.78 1.50 -1,284.37 4,539.84 66.70 87.00 2,747.14 2,638.14 1,286.49 2,754.52 5,947,306.46 561,520.28 1.50 -1,286.49 4,600.00 66.70 87.00 2,770.93 2,661.93 1,289.38 2,809.70 5,947,309.78 561,575.43 0.00 -1,289.38 4,700.00 66.70 87.00 2,810.49 2,701.49 1,294.19 2,901.41 5,947,315.31 561,667.10 0.00 -1,294.19 4,739.84 66.70 87.00 2,826.25 2,717.25 1,296.10 2,937.96 5,947,317.51 561,703.62 0.00 -1,296.10 4,800.00 66.40 89.60 2,850.19 2,741.19 1,297.74 2,993.11 5,947,319.57 561,758.76 4.00 -1,297.74 4,900.00 65.99 93.95 2,890.57 2,781.57 1,294.91 3,084.53 5,947,317.46 561,850.19 4.00 -1,294.91 4,947.61 65.84 96.03 2,910.00 2,801.00 1,291.13 3,127.83 5,947,314.02 561,893.51 4.00 -1,291.13 Ugnu C 5,000.00 65,71 98.32 2,931.50 2,822.50 1,285.16 3,175.23 5,947,308.42 561,940.95 4.00 -1,285.16 5,100.00 65.55 102.71 2,972.78 2,863.78 1,268.54 3,264.76 5,947,292.50 562,030.60 4.00 -1,268.54 5,200.00 65.52 107.11 3,014.21 2,905.21 1,245.13 3,352.69 5,947,269.77 562,118.70 4.00 -1,245.13 5,300.00 65.62 111.50 3,055.58 2,946.58 1,215.04 3,438.59 5,947,240.36 562,204.82 4.00 -1,215.04 5,400.00 65.84 115.88 3,096.70 2,987.70 1,178.42 3,522.04 5,947,204.40 562,288.55 4.00 -1,178.42 5,500.00 66.19 120.24 3,137.37 3,028.37 1,135.45 3,602.64 5,947,162.06 562,369.47 4.00 -1,135.45 5,600.00 66.66 124.58 3,177.38 3,068.38 1,086.34 3,679.98 5,947,113.56 562,447.19 4.00 -1,086.34 5,700.00 67.25 128.88 3,216.55 3,107.55 1,031.32 3,753.71 5,947,059.13 562,521.34 4.00 -1,031.32 5,800.00 67.95 133.14 3,254.68 3,145.68 970.67 3,823.45 5,946,999.03 562,591.54 4.00 -970.67 5,823.56 68.13 134.13 3,263.49 3,154.49 955.59 3,839.26 5,946,984.08 562,607.47 4.00 -955.59 5,830.31 68.13 134.13 3,266.00 3,157.00 951.23 3,843.76 5,946,979.75 562,612.00 0.00 -951.23 Ugnu B 5,900.00 68.13 134.13 3,291.96 3,182.96 906.20 3,890.18 5,946,935.08 562,658.77 0.00 -906.20 5,980.64 68.13 134.13 3,322.00 3,213.00 854.09 3,943.89 5,946,883.40 562,712.87 0.00 -854.09 Ugnu A 6,000.00 68.13 134.13 3,329.21 3,220.21 841.57 3,956.78 5,946,870.99 562,725.87 0.00 -841.57. 6,060.40 68.13 134.13 3,351.71 3,242.71 802.54 3,997.02 5,946,832.28 562,766.40 0.00 -802.54 6,100.00 68.30 136.04 3,366.41 3,257.41 776.50 4,022.98 5,946,806.44 562,792.56 4.50 -776.50 6,200.00 68.84 140.84 3,402.96 3,293.96 706.87 4,084.70 5,946,737.30 562,854.82 4.50 -706.87 6,300.00 69.51 145.60 3,438.53 3,329.53 632.02 4,140.63 5,946,662.90 562,911.32 4.50 -632.02 2/23/2007 10:18:59AM Page 5 of 9 COMPASS 2003.11 Build 48 ORIGINAL Cf3C1QC0~F11~~lp5 Alaska Database: Compass 2003.11 Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad well: Plan 1J-105 ' Wcllhore: 1J-105 Design: 1J-105(wp04) Planned Survey 1J-105 (wp04) Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • Sperry Cfri{ling ~®rvices Well Plan 1J-105 Plan RKB @ 109.OOft (Doyorr 141 (28+81)) Plan RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Map MD Inclination Azimuth TVD SSTVD +NI-S +E/-W Northing (ft) C') (°) (ft) (ft) (ft) (ft) (ft) 6,347.45 69.87 147.85 3,455.00 3,346.00 594.82 4,165.04 5,946,625.89 K13 6,400.00 70.31 150.32 3,472.90 3,363.90 552.44 4,190.42 5,946,583.71 6,500.00 71.23 154.98 3,505.85 3,396.85 468.59 4,233.78 5,946,500.22 6,600.00 72.27 159.60 3,537.18 3,428.18 381.01 4,270.42 5,946,412.93 6,700.00 73.41 164.15 3,566.70 3,457.70 290.23 4,300.12 5,946,322.40 6,800.00 74.65 168.65 3,594.23 3,485.23 196.81 4,322.71 5,946,229.17 6,900.00 75.98 173.10 3,619.60 3,510.60 101.33 4,338.03 5,946,133.82 7,000.00 77.39 177.49 3,642.64 3,533.64 4.38 4,346.01 5,946,036.94 7,042.04 78.00 179.32 3,651.60 3,542.60 -36.68 4,347.15 5,945,995.89 7,092.04 78.00 179.32 3,662.00 3,553.00 -85.59 4,347.73 5,945,947.00 W Sak D - 1J-105 D Top 01/09/07 7,100.00 78.00 179.32 3,663.65 3,554.65 -93.37 4,347.82 5,945,939.22 7,200.00 78.00 179.32 3,684.45 3,575.44 -191.18 4,348.98 5,945,841.43 7,288.33 78.00 179.32 3,702.81 3,593.81 -277.57 4,350.01 5,945,755.06 7,289.25 78.03 179.32 3,703.00 3,594.00 -278.47 4,350.02 5,945,754.16 W Sak C 7,300.00 78.35 179.29 3,705.20 3,596.20 -288.99 4,350.15 5,945,743.64 7,400.00 81.34 179.02 3,722.83 3,613.83 -387.40 4,351.60 5,945,645.25 7,440.73 82.55 178.92 3,728.54 3,619.54 -427.72 4,352.32 5,945,604.95 W Sak B - 1J-105 B Top (wp04j 7,500.00 82.55 178.92 3,736.22 3,627.22 -486.48 4,353.43 5,945,546.20 7,540.73 82.55 178.92 3,741.50 3,632.50 -526.86 4,354.19 5,945,505.84 7,600.00 82.61 177.13 3,749.15 3,640.15 -585.60 4,356.22 5,945,447.12 7,656.60 82.67 175.42 3,756.40 3,647.40 -641.61 4,359.87 5,945,391.14 7,684.81 82.67 175.42 3,760.00 3,651.00 -669.50 4,362.11 5,945,363.27 W Sak A4 7,700.00 82.67 175.42 3,761.94 3,652.94 -684.52 4,363.31 5,945,348.27 7,800.00 82.67 175.42 3,774.70 3,665.70 -783.38 4,371.24 5,945,249.48 7,900.00 82.67 175.42 3,787.45 3,678.45 -882.25 4,379.17 5,945,150.68 7,974.84 82.67 175.42 3,797.00 3,688.00 -956.24 4,385.10 5,945,076.75 W Sak A3 8,000.00 82.67 175.42 3,800.21 3,691.21 -981.12 4,387.10 5,945,051.89 8,100.00 82.67 175.42 3,812.97 3,703.97 -1,079.98 4,395.03 5,944,953.10 8,200.00 82.67 175.42 3,825.72 3,716.72 -1,178.85 4,402.95 5,944,854.31 8,251.09 82.67 175.42 3,832.24 3,723.24 -1,229.35 4,407.00 5,944,803.84 8,300.00 83.96 176.12 3,837.94 3,728.93 -1,277.80 4,410.59 5,944,755.43 8,400.00 86.60 177.55 3,846.16 3,737.16 -1,377.30 4,416.09 5,944,655.99 8,415.05 87.00 177.76 3,847.00 3,738.00 -1,392.31 4,416.71 5,944,640.98 W Sak A2 -1J-105 A Top (wp04) - 1J-105 MB_A CP2 01/09/07 8,500.00 89.52 178.16 3,849.58 3,740.58 -1,477.16 4,419.73 5,944,556.17 8,515.05 89.96 178.23 3,849.65 3,740.65 -1,492.20 4,420.20 5,944,541.13 7 5i8" Cas ing @ 8515' MD, 3850' TVD: 693' FSL, 1987 FWL - Sec36-T11N-R10E - 7 518" 8,600.00 92.48 178.64 3,847.84 3,738.84 -1,577.10 4,422.52 5,944,456.27 Map Fasting DLSEV Vert Section (ft) (°/100ff) (ft) 562,936.02 4.50 -594.82 562,961. 73 4.50 -552.44 563,005. 73 4.50 -468.59 563,043. 05 4.50 -381.01 563,073. 46 4.50 -290.23 563,096. 78 4.50 -196.81 563,112. 84 4.50 -101.33 563,121. 57 4.50 -4.38 563,123. 04 4.50 36.68 563,124. 00 0.00 85.59 563,124. 15 0.00 93.37 563,126. 08 0.00 191.18 563,127. 78 0.00 277.57 563,127. 79 3.00 278.47 563,128. 00 3.00 288.99 563,130. 22 3.00 387.40 563,131. 26 3.00 427.72 563,132. 83 0.00 486.48 563,133. 91 0.00 526.86 563,136. 39 3.00 585.60 563,140. 48 3.00 641.61 563,142. 93 0.00 669.50 563,144. 25 0.00 684.52 563,152. 95 0.00 783.38 563,161. 65 0.00 882.25 563,168. 16 0.00 956.24 563,170. 35 0.00 981.12 563,179. 05 0.00 1,079.98 563,187. 75 0.00 1,178.85 563,192. 19 0.00 1,229.35 563,196. 16 3.00 1,277.80 563,202. 44 3.00 1,377.30 563,203. 17 3.00 1,392.31 563,206. 85 3.00 1,477.16 563,207. 44 3.00 1,492.20 563,210.43 3.00 1,577.10 2/23/2007 10:18:59AM Page 6 of 9 COMPASS 2003.11 Build 48 • ~€?t'14C0~'ft~~l~?S Alaska Halliburton Company Planning Report -Geographic • 8p®rry DriEiing Services Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Cornpany: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB, @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB`@ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-105 ~, Design: 1J-105 (wp04) Planned Survey 1J-105 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +N1-S +E/_y~ Northing Easting DLSEV Vert Section (ft) (~) (~) (ft) (ft) (ft) (ft) eft) (ft) (°1100fC) (ft) 8,632.03 93.43 178.79 3,846.19 3,737.19 -1,609.07 4,423.24 5,944,424.30 563,211.40 3.00 1,609.07 8,700.00 93.43 178.79 3,842.13 3,733.13 -1,676.91 4,424.68 5,944,356.48 563,213.36 0.00 1,676.91 8,708.80 93.43 178.79 3,841.60 3,732.60 -1,685.69 4,424.87 5,944,347.71 563,213.62 0.00 1,685.69 8,797.52 91.98 177.76 3,837.41 3,728.41 -1,774.27 4,427.54 5,944,259.16 563,216.98 2.00 1,774.27 8,800.00 91.98 177.76 3,837.33 3,728.33 -1,776.74 4,427.63 5,944,256.68 563,217.09 0.00 1,776.74 8,900.00 91.98 177.76 3,833.87 3,724.87 -1,876.61 4,431.54 5,944,156.86 563,221.78 0.00 1,876.61 9,000.00 91.98 177.76 3,830.42 3,721.42 -1,976.47 4,435.45 5,944,057.04 563,226.46 0.00 1,976.47 9,100.00 91.98 177.76 3,826.96 3,717.96 -2,076.34 4,439.35 5,943,957.22 563,231.15 0.00 2,076.34 9,200.00 91.98 177.76 3,823.51 3,714.51 -2,176.20 4,443.26 5,943,857.40 563,235.83 0.00 2,176.20 9,300.00 91.98 177.76 3,820.05 3,711.05 -2,276.06 4,447.17 5,943,757.58 563,240.52 0.00 2,276.06 9,400.00 91.98 177.76 3,816.60 3,707.60 -2,375.93 4,451.07 5,943,657.76 563,245.20 0.00 2,375.93 9,500.00 91.98 177.76 3,813.14 3,704.14 -2,475.79 4,454.98 5,943,557.94 563,249.89 0.00 2,475.79 9,600.00 91.98 177.76 3,809.69 3,700.69 -2,575.66 4,458.88 5,943,458.12 563,254.57 0.00 2,575,66 9,700.00 91.98 177.76 3,806.23 3,697.23 -2,675.52 4,462.79 5,943,358.30 563,259.26 0.00 2,675.52 9,800.00 91.98 177.76 3,802.78 3,693.78 -2,775.38 4,466.70 5,943,258.48 563,263.95 0.00 2,775.38 9,822.52 91.98 177.76 3,802.00 3,693.00 -2,797.87 4,467.58 5,943,236.00 563,265.00 0.00 2,797.87 1J-105 MB A CP3 01109/07 9,900.00 91.23 177.95 3,799.83 3,690.83 -2,875.27 4,470.47 5,943,158.64 563,268.50 1.00 2,875.27 9,923.55 91.00 178.01 3,799.37 3,690.37 -2,898.80 4,471.30 5,943,135.11 563,269.51 1.00 2,898.80 10,000.00 91.00 178.01 3,798.04 3,689.04 -2,975.19 4,473.95 5,943,058.75 563,272.76 0.00 2,975.19 10,100.00 91.00 178.01 3,796.29 3,687.29 -3,075.12 4,477.42 5,942,958.87 563,277.01 0.00 3,075.12 10,200.00 91.00 178.01 3,794.54 3,685.54 -3,175.04 4,480.89 5,942,858.98 563,281.26 0.00 3,175.04 10,288.08 91.00 178.01 3,793.00 3,684.00 -3,263.06 4,483.95 5,942,771.00 563,285.00 0.00 3,263.06 1J-105 MB A CP4 01!09/O7 10,300.00 90.97 177.90 3,792.80 3,683.80 -3,274.96 4,484.37 5,942,759.10 563,285.52 1.00 3,274.96 10,400.00 90.66 176.94 3,791.37 3,682.37 -3,374.85 4,488.87 5,942,659.26 563,290.80 1.00 3,374.85 10,464.87 90.47 176.33 3,790.73 3,681.73 -3,439.61 4,492.68 5,942,594.54 563,295.11 1.00 3,439.61 10,500.00 90.47 176.33 3,790.45 3,681.45 -3,474.66 4,494.93 5,942,559.51 563,297.63 0.00 3,474.66 10,600.00 90.47 176.33 3,789.63 3,680.63 -3,574.45 4,501.34 5,942,459.78 563,304.82 0.00 3,574.45 10,700.00 90.47 176.33 3,788.82 3,679.82 -3,674.25 4,507.74 5,942,360.05 563,312.00 0.00 3,674.25 10,800.00 90.47 176.33 3,788.00 3,679.00 -3,774.04 4,514.15 5,942,260.32 563,319.19 0.00 3,774.04 10,900.00 90.47 176.33 3,787.18 3,678.18 -3,873.83 4,520.56 5,942,160.59 563,326.37 0.00 3,873.83 10,922.66 90.47 176.33 3,787.00 3,678.00 -3,896.44 4,522.01 5,942,138.00 563,328.00 0.00 3,896.44 1J-105 MB A CP5 01109!07 11,000.00 89.70 176.22 3,786.89 3,677.89 -3,973.62 4,527.04 5,942,060.87 563,333.63 1.00 3,973.62 11,061.21 89.09 176.14 3,787.53 3,678.53 -4,034.68 4,531.11 5,941,999.84 563,338.18 1.00 4,034.68 11,100.00 89.09 176.14 3,788.14 3,679.14 -4,073.38 4,533.73 5,941,961.17 563,341.10 0.00 4,073.38 11,200.00 89.09 176.14 3,789.72 3,680.72 -4,173.14 4,540.47 5,941,861.47 563,348.61 0.00 4,173.14 11,300.00 89.09 176.14 3,791.30 3,682.30 -4,272.90 4,547.20 5,941,761.78 563,356.13 0.00 4,272.90 11,400.00 89.09 176.14 3,792.88 3,683.88 -4,372.66 4,553.94 5,941,662.08 563,363.65 0.00 4,372.66 11,500.00 89.09 176.14 3,794.46 3,685.46 -4,472.42 4,560.68 5,941,562.39 563,371.16 0.00 4,472.42 11,600.00 89.09 176.14 3,796.04 3,687.04 -4,572.18 4,567.42 5,941,462.69 563,378.68 0.00 4,572.18 11,700.00 89.09 176.14 3,797.62 3,688.62 -4,671.95 4,574.15 5,941,363.00 563,386.19 0.00 4,671.95 11,724.07 89.09 176.14 3,798.00 3,689.00 -4,695.96 4,575.77 5,941,339.00 563,388.00 0.00 4,695.96 BHL ~ 11724' MD, 3798' TVD: 2511' FNL, 2139' FWL - Sec 01-T10N-R10E - 4 1/2" -1 J-105 A Toe 01/09/07 2/23/2007 10:18:59AM Page 7 of 9 COMPASS 2003.11 Build 48 t ~~~ • CanticoPhitlips fltllaska Halliburton Company Planning Report -Geographic • Sperry Drilling services atabase: Compass 2003.11 ~ Local Co-ordinate Reference: Well Plan 1J-105 ~mpany: C;onocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) -oject: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) te: Kuparuk 1J Pad North Reference: True ell: Plan 1J-105. Survey Calculation Method: Minimum Curvature elibore: 1J-105 'sign: 1J-105 (wp04) Geologic Targets 1J-105 7VD Target Namo +N/-S +EI-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,793.00 1J-105 MB_A CP4 01/09/07 -3,263.06 4,483.95 5,942,771.00 563,285.00 - Polygon Point 1 0.00 0.00 5,942,771.00 563,285.00 Point 2 -633.39 38.06 5,942,138.00 563,328.00 3,787.00 1J-105 MB_A CP5 01/09/07 -3,896.44 4,522.01 5,942,138.00 563,328.00 - Polygon Point 1 0.00 0.00 5,942,138.00 563,328.00 Point 2 -799.54 53.77 5,941,339.00 563,388.00 3,847.00 1J-105 A Top (wp04) -1,392.31 4,416.71 5,944,640.98 563,203.17 - Point 3,798.00 1J-105 A Toe 01/09107 -4,695.96 4,575.77 5,941,339.00 563,388.00 - Point 3,802.00 1J-105 MB_A CP3 01/09/07 -2,797.87 4,467.58 5,943,236.00 563,265.00 - Polygon Point 1 0.00 0.00 5,943,236.00 563,265.00 Point 2 -465.20 16.37 5,942,771.00 563,285.00 3,847.00 1J-105 MB_A CP2 01/09/07 -1,499.31 4,416.71 5,944,534.00 563,204.00 - Polygon Point 1 0.00 0.00 5,944,534.00 563,204.00 Point 2 -1,298.61 50.87 5,943,236.00 563,265.00 3,662.00 1J-105 D Top 01/09/07 -85.59 4,347.73 5,945,947.00 563,124.00 - Point 3,905.00 1J-105 MB_A Heel 01/09!07 -85.59 4,347.73 5,945,947.00 563,124.00 - Polygon Point 1 0.00 0.00 5,945,947.00 563,124.00 Point 2 -424.47 11.69 5,945,523.00 563,139.00 3,893.00 1J-105 MB_A CP1 01/09/07 -509.73 4,359.42 5,945,523.00 563,139.00 - Polygon Point 1 0.00 0.00 5,945,523.00 563,139.00 Point 2 -989.69 57.28 5,944,534.00 563,204.00 3,728.54 1J-105 B Top (wp04) -427.72 4,352.32 5,945,604.95 563,131.26 - Point Prognosed Casing Points Measured Depth (ft) 3,293.57 8,515.05 11,724.06 Vertical Depth (ft) 2,250.00 3,849.65 3,798.00 Casing diameter (") 10-3/4 7-5/8 4-1/2 Hole Diameter ('7 13-1 /2 9-718 6-314 i 2/23/2007 10:18:59AM Page 8 of 9 COMPASS 2003.11 Build 48 ~~~ • CoinocoPhi[lips Alaska Database: Compass 2003.11 Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-105 Wellbore: I.i-105 Design: I J-105 (wp04) ~~ Halliburton Company °~,1..~.~ l!&~ ~~` ~i Planning Report -Geographic gperry p~i[ling Eeryices Local Co-ordinate Reference: Well Plan 1J-105 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method; Minimum Curvature Pro nosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (') (°) ~~) (~) (ft) Name 1,648.94 47.24 56.34 1,512.00 301.03 387.17 Pfrost 1,876.16 53.76 56.34 1,660.00 396.48 530.50 T3 2,561.79 66.64 58.76 1,960.00 734.75 1,043.66 K15 3,293.57 66.70 67.00 2,250.00 1,027.24 1,647.66 Casing Pt 4,947.61 65.84 96.03 2,910.00 1,291.13 3,127.83 Ugnu C 5,830.31 68.13 134.13 3,266.00 951.23 3,843.76 Ugnu B 5,980.64 68.13 134.13 3,322.00 854.09 3,943.89 Ugnu A 6,347.45 69.87 147.85 3,455.00 594.82 4,165.04 K 13 7,092.04 78.00 179.32 3,662.00 -85.59 4,347.73 W Sak D 7,289.25 78.03 179.32 3,703.00 -278.47 4,350.02 W Sak C 7,440.73 82.55 178.92 3,728.54 -427.72 4,352.32 W Sak B 7,684.81 82.67 175.42 3,760.00 -669.50 4,362.11 W Sak A4 7,974.84 82.67 175.42 3,797.00 -956.24 4,385.10 W Sak A3 8,415.05 87.00 177.76 3,847.00 -1,392.31 4,416.71 WSakA2 Pfan Annotations Measured Depth (ft) 28.00 3,293.57 8,515.05 11,724.07 Vertical Local Coordinates Depth +N/-S +E/-W Comment SHL: 2187' FSL, 2432' FEL -Sec35-T11 N-R10E 2,250.00 1,027.24 1,647.66 10 3/4" Casing @ 3294' MD, 2250' TVD: 2066' FEL, 783' FEL -Sec35-T11 N-F 3,849.65 -1,492.20 4,420.20 7 5/8" Casing @ 8515' MD, 3850' TVD: 693' FSL, 1987' FWL - Sec36-T11 N-R 3,798.00 -4,695.96 4,575.77 BHL @ 11724' MD, 3798' TVD: 2511' FNL, 2139' FWL - Sec01-T10N-R10E 2/23/2007 10:18:59AM Page 9 of 9 COMPASS 2003.11 Build 48 Oi=1GINAL ConocoPhillips Alaska • Plan: 1J-105 (wp04) Sperry Drilling Services Anticollision Summary 23 February, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-105 1J-105 Local Coordinate Origin: Centered on Well Plan 1J-105 Viewing Datum: Plan RKB @ 109.OOft (Doyon 141 (28+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~~;~~ _ i3perry Driliing 3®rvices 0^nIGINAL N O p ~~ o> ~ R ° 8 ~ p ~ F _ ~ a a a a oon a ~ ~ v ° y ~ N m 3 ~ ~. ~~ ~ i s m~n1° ~ •t ffi g ~ 8 ~ ~ o ~ '-'~ r _` r a 888 a~RF~~ $S ^~8 8; 6 g °~ w -` ~ o m o ~ ° R ~x~~f~~~$* ~ s ~s~r~°R~o~ m_ ~ ~ N M a c ~ ~o8s8888g8~8g8$8$88~8 ~,8$$$~8~8~8 N ~ E 01u ~ ~ ~~ ~ ,°, d88SSSR8~48$888SSS888S88888888888 O m a `° ° /~ ~ i ~ ~ < o 0 o e o U r2 y ~ m ~ u ~ 388 8~m 8 8 ~~R~3 ~. Q W~.X .y '~ _ N / o "88 S~R~~~ ~A8 ^~8 ~aSB :: o ~'t + I I' N ~ssss~ ~ ss xs s ss s ~„s c tie ~. ~' : ~ . / ~ z~ s~ ~$~r^°.,~~,~,~ .,~~~~~~~°~~,a~ '`~~ ~ % ~ ~sssxx~~s$sa m m~ ~ - ~ ~ X88 °°R° 588 8 _R~88<^<$8 0 0 m / ~ ~ M ~ X8,8 a3`$`$n~8 qy$,S °° 8 °S8y ne ~ 1 ~vr~in ,%i3$~~r3si "~ $ mmm$'i$3$r'Bn 7 - o - ~~ ~ U en ~ o° ~` °v t•1 N w O ~ N F ci C A ~ L ~ O O Y ~ 0 O O O O O O O O O O O O O O O O N O O O O~ O M O t(7 0 0 0 0 0 0 0 0 0 0 ~ 10 Z u ~ to O~ O N M I~ O N ~A O O O O O O O O M H ~ ~ 'o ~ F-- N o r .- e- .- .- N N N M 7 M O n W O r r o mEU~Qm U I I I I I I o a`,~~nr-w~ ~ m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O c .~ .~ y .~ ~ N M O M O M O M O X 0 0 0 0 0 0 0 0 0 U 'p~ O E 0 0 0 p N~ I~ O N E I~ O N ~ 0 0 0 0 0 0 0 0 W.L.. y .L. t .L. LL r' ~ a- r N N N M V ~ CO I~ M m O J ~N~U)'L Q C C ~ F- O Q N O C W - u ~ mWdJW E - } O >R Z U > ~ N W V ~ °m O O ~ =' U o o p ~°p ~ O o ~ y L C7 ~= ~ _ 3 ~ -- ry n m m ' / ~ // ~ r 1 ~ ~ N _ / / ~ ~ _~ W C V > N N ^,. - f u i' ~ a ~ f V~ ° ~~ Y o, o \ 'rf ( C . ~ ~ `~- ~ / T ~ `: ray 2 0 O ~ c ~ d .- 0 ri A {~, ~~if .:ice~ ~A ~ `~\ ( s.. ~K ' + 5 v z 3 a N a ~ ~ ~ \ ~ ~"'/ rF~,. :. _ ~ r-l 't ~6~' r'~ o Lz' ~ o ~ ~ w m m ti m c •~ U ~ ~\ ~ ~ Gin / n. F c ~m~ z ccccr \ ~i Sr ~ 1 ~ '~ o ~_ ,^_ . _- "9~~ ~ - ~i~' : t~~ K.. ~ ~~ \ ~`9~Y`~' o ~ N C Z °a' a r a"i ~ c ~-° p o o ~°n 7 ~~3 ~ P r~ N \ ~ \ \ ° r c ~ ~ ~ O ~oooo r ~ ~ ~ ~i a n. 3 w ~ ° ~n ro s ~ ~n A ~ _ ~ - ORIGINAL ''~°' Halliburton Company ~~~~~®~~~ Anticollision Report Sperry IDriiiing Services Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-105 Well Error: O.OOft Reference Wellbore 1J-105' Reference Design: 1J-105 (wp04) Local Co-ordinate Reference: Well Plan 1J-105 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Datahase: Compass 2003.11 Offset TVD Reference: Offset Datum Reference I.!-IirS ~wp04) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer 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 1,369.61ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma __ __ Survey Tool Frogram Dafe 2C07 ~, From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 u00.00 1J-105 (wp04) (1J-105) CB-GYRO-SS Camera based gyro single shot 800.00 11,724.07 1J-105 (wp04) (1J-105) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 3:14:35PM Page 2 of 5 COMPASS 2003.11 Build 48 -~~~~~~a1~P '"*~'` Hatliburton Company ~,~-~~~~ ~"`~~°;' Gonoro~tl~ps Anticollision Report J~ J qi Sperry Drilling Services Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-105 I Project: Kuparuk River Unit TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) ~~ Reference Site: Kuparuk 1J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Weli: Plan 1J-105 Survey Calculation Method: Minimum Curvature Well Enor: O.OOft Output errors are at 2.00 sigma' Reference Wellbore 1J-105 Database: Compass 2003.11 Reference Design: 1J-105 (wp04) Offset TVD Reference:. Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning ' Site Name Depth Depth distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1 J-03 - 1 J-03 - 1 J-03 365.97 375.00 79.09 6.64 72.45 Pass -Major Risk 1 J-09 - 1 J-09 - 1 J-09 293.14 300.00 148.26 5.36 142.90 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 316.20 325.00 217.04 5.96 211.08 Pass -Major Risk 1 J-101 - 1 J-101 - 1 J-101 778.88 775.00 82.17 17.06 65.11 Pass -Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 778.88 775.00 82.17 17.06 65.11 Pass -Major Risk 1J-101 - 1J-101 L1 PB1 - 1J-101 L1 PB1 778.88 775.00 82.17 17.06 65.11 Pass -Major Risk 1J-101 - 1J-101 L2 - 1J-101 L2 778.88 775.00 82.17 17.06 65.11 Pass -Major Risk 1J-101 - 1J-101PB1 - 1J-101PB1 778.88 775.00 82.17 17.06 65.11 Pass -Major Risk 1J-102 - 1J-102 - 1J-102 237.69 250.00 61.26 4.83 56.43 Pass -Major Risk 1J-102 - 1J-102 L1 - 1J-102 L1 237.69 250.00 60.62 5.12 55.51 Pass -Major Risk 1J-102 - 1J-102 L2 - 1J-102 L2 237.69 250.00 61.26 4.83 56.43 Pass -Major Risk 1J-102 - 1J-102 L2 P61 - 1J-102 L2 P61 237.69 250.00 61.26 4.83 56.43 Pass -Major Risk 1J-102 - 1J-102 L2 PB2 - 1J-102 L2 PB2 237.69 250.00 60.62 5.12 55.51 Pass -Major Risk 1J-102 - 1J-102 PB1 - 1J-102 PB1 237.69 250.00 60.62 5.12 55.51 Pass -Major Risk 1J-102 - 1J-102 PB2 - 1J-102 PB2 237.69 250.00 60.62 5.12 55.51 Pass -Major Risk 1J-102 - 1J-102 P63 - 1J-102 P63 237.69 250.00 60.62 5.12 55.51 Pass -Major Risk 1J-109 - 1J-109 - 1J-109 384.27 400.00 99.00 8.53 90.47 Pass -Major Risk 1J-109 - 1J-109 P61 - 1J-109PB1 384.27 400.00 99.00 8.43 90.58 Pass -Major Risk 1J-109 -Plan 109a L1 - 1J-109a L1 (wp02) 396.78 400.00 99.26 8.82 90.45 Pass -Major Risk 1J-109 -Plan 1J-109a - 1J-109a (wp02) 396.78 400.00 99.26 8.82 90.45 Pass -Major Risk 1J-109 -Plan 1J-109a L2 - 1J-109a L2 (wp02) 396.78 400.00 99.26 8.82 90.45 Pass -Major Risk 1J-115 - 1J-115 - 1J-115 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115L1 - 1J-115L1 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115L1PB1 - 1J-115L1PB1 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1 J-115 - 1 J-115L1 PB2 - 1 J-115L1 PB2 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115L2 - 1J-115L2 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115L2P61 - 1J-115L2PB1 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115L2PB2 - 1J-115L2PB2 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115P61 - 1J-115PB1 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115P62 - 1J-115P62 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115PB3 - 1J-115PB3 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-115 - 1J-115PB4 - 1J-115PB4 346.11 350.00 220.65 7.66 212.99 Pass -Major Risk 1J-14 - 1J-14 - 1J-14 11,350.11 7,600.00 198.07 165.72 32.35 Pass -Major Risk 1J-152 - 1J-152 - 1J-152 347.13 350.00 152.23 7.56 144.66 Pass -Major Risk 1J-152 - 1J-152 L1 - 1J-152 L1 347.13 350.00 152.26 7.56 144.70 Pass -Major Risk 1J-152 - 1J-152 L2 - 1J-152 L2 347.13 350.00 152.26 7.56 144.70 Pass -Major Risk 1J-152 - 1J-152 L2 PB1 - 1J-152 L2 P81 347.13 350.00 152.26 7.56 144.70 Pass -Major Risk 1J-152 - 1J-152 PB1 - 1J-152 PB1 347.13 350.00 152.26 7.56 144.70 Pass -Major Risk 1J-152 - 1J-152 PB2 - 1J-152 PB2 347.13 350.00 152.23 7.56 144.66 Pass -Major Risk 1J-154 - 1J-154 - 1J-154 393.60 400.00 145.62 8.71 136.92 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 393.60 400.00 145.62 8.71 136.92 Pass -Major Risk 1J-154 - 1J-154 L2 - 1J-154 L2 393.60 400.00 145.62 8.71 136.92 Pass -Major Risk 1J-156 - 1J-156 - 1J-156 274.99 275.00 158.82 6.10 152.72 Pass -Major Risk 1J-156 - 1J-156L1 - 1J-156L1 274.99 275.00 158.82 6.10 152.72 Pass -Major Risk 1J-156 - 1J-156L1P61 - 1J-156L1PB1 274.99 275.00 158.82 6.10 152.72 Pass -Major Risk 1 J-156 - 1 J-156L2 - 1 J-156L2 274.99 275.00 158.82 6.10 152.72 Pass -Major Risk 1 J-159 - 1 J-159 - 1 J-159 846.06 900.00 183.66 18.02 165.64 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 846.06 900.00 183.66 18.02 165.64 Pass -Major Risk 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 P61 846.06 900.00 183.66 18.02 165.64 Pass -Major Risk 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 PB2 846.06 900.00 183.66 18.02 165.64 Pass -Major Risk 1J-159 - 1J-159 L2 - 1J-159 L2 846.06 900.00 183.66 18.02 165.64 Pass - Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 3:14:35PM Page 4 of 5 COMPASS 2003.11 Build 48 ,, C_7 COl'ldCOp`f'11~~1~5 Alaska Halliburton Company Anticollision Report v Sperry Drilling Services Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-105 Project: Kuparuk River Unit ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: ' Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-105 Database: Compass 2003:11 Reference Design: 1 J-105 (wp04) Offset ND Reference: .Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ftj (ftj (ft) kr.ipar!_iB iJ Pad 1J-159 - 1J-159 PB1 - 1J-159 PB1 846.06 900,00 183.66 18.02 165.64 Pass -Major Risk 1J-164 - 1J-164 - 1J-164 320.20 325.00 281.47 7.11 274.36 Pass -Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 320.20 325.00 281.47 7.11 274.36 Pass -Major Risk 1J-164 - 1J-164 L2 - 1J-164 L2 320.20 325.00 281.47 7.11 274.36 Pass -Major Risk 1J-164 - 1J-164 L2 PB1 - 1J-164 L2 PB1 320.20 325.00 281.47 7.11 274.36 Pass -Major Risk Plan 1J-105 - 1J-105 L1 - 1J-105 L1 (wp04) 7,450.00 7,450.00 0.12 0.60 -0.48 FAIL -Major Risk Plan 1J-105 - 1J-105 L2 - 1J-105 L2 (wp04) 7,100.00 7,100.00 0.09 0.60 -0.51 FAIL -Major Risk Plan 1J-107 -Plan 1J-107 - 1J-107 (wp03) 373.99 375.00 40.90 8.11 32.79 Pass -Major Risk Plan 1J-107 -Plan 1J-107 L1 - 1J-107 L1 (wp03) 373.99 375.00 40.90 8.11 32.79 Pass -Major Risk Plan 1J-107 -Plan 1J-107 L2 (wp03) - 1J-107 L2 ~ 373.99 375.00 40.90 8.11 32.79 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 E Lateral - 1J 358.62 375.00 160.90 7.82 153.08 Pass -Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 Pilot - 1J-12 I 358.62 375.00 160.90 7.82 153.08 Pass -Major Risk Plan 1 J-112 Kuparuk Prelim -Plan 1 J-12 W Later 358.62 375.00 160.90 7.82 153.08 Pass -Major Risk Plan 1 J-120 -Plan 1J-120 - 1 J-120 (wp06) 321.39 325.00 320.79 6.98 313.81 Pass -Major Risk Plan 1 J-120 -Plan 1J-120 L1 - 1J-120 L1 (wp06) 321.39 325.00 320.79 6.98 313.81 Pass -Major Risk Plan 1J-120 -Plan 1J-120 L2 - 1J-120 L2 (wp06) 321.39 325.00 320.79 6.98 313.81 Pass -Major Risk Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) 11,322.86 7,550.00 609.28 173.39 435.90 Pass -Major Risk Plan 1J-133 - 1J-133 - 1J-133 Intermediate 297.12 300.00 579.53 6.70 572.83 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispc 324.57 325.00 166.77 6.26 160.51 Pass -Major Risk Plan 1 J-158 - 1 J-158 - 1 J-158 (wp07) 310.49 325.00 176.86 6.77 170.09 Pass -Major Risk Plan 1J-158 - 1J-158 L1 - 1J-158 L1 (wp07) 310.49 325.00 176.86 6.77 170.09 Pass -Major Risk Plan 1J-158 - 1J-158 L2 - 1J-158 L2 (wp07) 310.49 325.00 176.86 6.77 170.09 Pass -Major Risk Plan 1J-160 -Plan 1J-160 - 1J-160 (wp08) 310.18 325.00 202.46 6.88 195.58 Pass -Major Risk Plan 1J-160 -Plan 1J-160 L1 - 1J-160 L1 (wp08) 310.18 325.00 202.46 6.88 195.58 Pass -Major Risk Plan 1J-160 -Plan 1J-160 L2 - 1J-160 L2 (wp08) 310.18 325.00 202.46 6.88 195.58 Pass -Major Risk Rig: 1J-103 - 1J-103 - 1J-103 729.97 725.00 42.56 15.82 26.74 Pass -Major Risk Rig: 1J-103 - 1J-103 L1 - 1J-103 L1 729.98 725.00 42.57 15.82 26.75 Pass -Major Risk Rig: 1J-103 - 1J-103 L1 PB1 - 1J-103 L1 PB1 729.97 725.00 42.56 15.82 26.74 Pass -Major Risk Rig: 1J-103 - 1J-103 L2 - 1J-103 L2 729.98 725.00 42.57 15.82 26.75 Pass -Major Risk Rig: 1J-103 - 1J-103P61 - 1J-103P61 729.97 725.00 42.56 15.82 26.74 Pass -Major Risk Rig: 1J-103 - 1J-103PB2 - 1J-103PB2 729.97 725.00 42.56 15.82 26,74 Pass -Major Risk Rig: 1J-103 - 1J-103P63 - 1J-103PB3 729.97 725.00 42.56 15.82 26.74 Pass -Major Risk Rig: 1J-118 - 1J-118 - 1J-118 6,681.65 6,275.00 316.58 116.25 200.33 Pass -Major Risk Rig: 1J-118 - 1J-118 L1 - 1J-118 L1 6,681.65 6,275.00 316.58 116.83 199.75 Pass -Major Risk Rig: 1J-118 - 1J-118 L1 - 1J-118 L1 (wp07) 6,734.00 6,250.00 320.79 117.98 202.80 Pass -Major Risk Rig: 1J-118 - 1J-118 L2 - 1J-118 L2 6,681.65 6,275.00 316.58 116.25 200.33 Pass -Major Risk Rig: 1J-118 - 1J-118 L2 - 1J-118 L2 (wp07) 6,734.00 6,250.00 320.79 117.98 202.80 Pass -Major Risk Rig: 1J-118 - 1J-118 PB1 - 1J-118 PB1 6,681.65 6,275.00 316.58 116.25 200.33 Pass -Major Risk Rig: 1J-118 - 1J-118 PB2 - 1J-118 P62 6,681.70 6,275.00 316.58 116.26 200.33 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 365.23 375.00 127.13 7.26 119.87 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 423.71 425.00 186.55 11.45 175.10 Pass -Major Risk WSP-04 -WSP-04 -WSP-04 362.61 375.00 243.40 7.37 236.02 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 510.56 525.00 72.64 12.99 59.66 Pass -Major Risk WSP-1 S -WSP-1 S -WSP-1 S 668.09 675.00 19.77 23.54 -3.77 FAIL -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 3:14:35PM Page 5 of 5 COMPASS 2003.11 Build 48 02161NAL iJ-105I~`illin Hazards ~imma ry (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval.. Gas Hydrates Moderate . Control drill, Reduced pump rates, Reduced ~ drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned .mud parameters, 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 Close Approach to Moderate Gyro use, monitor MWD magnetic P&A'd Well interference, monitor mud for brine influx from P&A'd well 9-7/8" Open Hole. / 7-5l8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low ~ .Control drill, reduced pump rates, reduced ~ drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir ~ Low ~ BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo. , LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased Pressure ~ mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-105 Drilling Hazards Summary 2/23/2007 6:04 PM CemCADE~ Preliminary Job Design 10 3/4" Surface reliminary Job Design based on limited input data. For estimate purposes only. Rig; Doyon 15 Location: West Salo Client: ConocoPhillips Alaska, Inc. Revision Date: 2/23/2007 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445. email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91..5# casing at 80' MD < Base of Permafrost at 1,650' MD (1,512' ND) < Top of Tail at 2,493' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 3,293' MD (2,250' TVD) Mark of Schlumberger 3 '" .~~~li~i~~ :.,, ~.: Volume Calculations and Cement SVstems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top. of the tail slurry is designed to beat 2,493' MD. Lead Slurrv Minimum pump time: 230 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x (1650' - 80') x 3.50 (250% excess) = 1998.5 ft3 0.3637 ft3/ft x (2493' - 1650') x 1.35 (35% excess) = 413.9fit3 109.2 ft3 + 1998.5 ft3+413.9 ft3 = 2521.6 ft3 2521.6 ft3/ 4.45 ft3/sk = 566.7 sks Round up to 570 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 170 min. (pump time plus 120 min.) DeepCRETE C~ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (3293' - 2493') x 1.35 (35% excess) = 392.8 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 392.8 ft3 + 43.2 ft3 = 436 ft3 436 ft3/ 2.47 ft3/sK = 176.5 sks Round up to 180 sks BHST = 49~, Estimated BHCT = 65~'. (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) (boll (min). lminl CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 0 0.0 25.0 Lead Slurry 7 452 64.6 89.6 Tail Slurry 6 79 13.2 102.8 Drop Top Plug 8.0 110.8 Displacement 6 294 49.0 159.8 Slow Rate 3 15 5.0 164.8 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: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. !~';~~~ Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Ina Revision Date: 2/23/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com I f Previous Csg. < 10 3/4", 45.5# casing at 3,293' MD < Top of Tail at 4,497 MD i < 7 5/8", 29.7# casing in 9 7/8" OH TD at 8,515' MD (3,850' TVD) ~ " ~~ „~ CemCADE Preliminary Job Design ~ ' 7.625" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. VoFume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed to isolate the Ugnu C by bringing cement 500' above the formation top @ 4947'. MD, 2910' TVD - (TOC = 4447 MD, 4068' MD annular length). Tail Slurry Minimum thickening time: 210 min. (Pump time plus 120 min.) DeepCRETE C 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 4068' x 1.25 (25% excess) _ 1092.3 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 1092.3 ft3 + 20.6 ft3 = 1112.9 ft3 1112.9 ft3/ 2.25 ft3/sk = 494.6 sks Round up to 500 sks BHST = 91 ~, Estimated BHCT = 77~. (BHST calculated using a gradienf of 2.6`F/100 ft below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm) (bbll (min)e. (mint CW 100 5 30 6.0 6.0 Drop Bottom Plug 10.0 16.0 MudPUSH II 5 30 6.0 22.0 Tail Slurry 5 200- 40.0 62.0 Drop Top Plug 10.0 72.0 Displacement 6 367 61.2 133.2 Slow Rate 3 20 6.7 139.9 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv - 19-22, TY ~ 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~~~~~... • • -~ ~n~~ q =o » O . ~m O i o M a ~es~ Z 0 o a ~ 0 8 ze ------- N ~~_~ °o 0 0 0 - - - o o ~ 0 o ~ ~ i ~ 0 rn ~ _- - - - --- ------- -- ------- ---- __ o 0 _ o a m ~ a 3 s ~ o o _. - __ . _ ...o . ~- . _ ---..__._ o i O 0 r i ~ O r i ~ -o u~ 10 V O ~ ~ i ~ N p _>d~~ ~ to 3 . . ~ ~ I ~ _ w ~ - ~ _ ~~ _ __i ~ ~ °o O r C .. I '~,~ v ~~~ ~ J n I ~~ I ~ ~ t aQa c I i ~ ! O ... N ~~ d ~ 7 0 YY a ~ ' _.... _. ~ I ._ . . . _ _ ~ -___ _ ..-..-..__..- _.. O ~ R W r u y a•- m c m .o N ~ d ~ O ~ a _____ I _ _._ ~~ ~ - - o O I ~ ' m I _1 M o J ~ ~ ,~ ~ O i~ ~ _ _ ~ _ _~ Q N N O y ~ O ~ ., ........ . .___ - ...- -- ---- -----~--- --.._._.._ O d `~ u ~ v i -NOo ` u°m'c~. E uai ~ 3. v E ~ ~ HV °oa'^ i O ~d'. w8om r ..rz~ ~=1e meu $t ot =,w _w~='Eoa ~ _~N o~~, - O O O "w~° H -viii u' 8 ~~¢a ~ as - _ o 0 o N N Y q U ~ O .--- I -- -- -- - --- - __ ._ O M = ~ ~ ` 0 II I_~ ~ O i +y / C l - -- -- O 0 .. m I i ~ ~ 0 a L O O O O O O O O O O O O O O O O O O O O O O O O O N O V O O O ~ ~ ~ (U!/u OOOZ) (+)43~oN/1-1U3~oS OR161NAL + ~ ~R ~~ ~~ ,,~ ~ _ °, ~ *a~ ~.. ~, ~' V. `*~~ AA r 1 r i i i i i - ~ i i i i i e,._.... v..,:._.~,..,.,..~,,~.. II d ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 1 ~ j a O J d ~ 1 t ~~~N 3 _ ~ ~\ ~ ~ Y =~ J ° ~ Q. 7 f0 ` QQn. o - ~~~ ~ ~ ' ~ 3 ~ YYd~ ~ ~ =-m ~ ~ ~Q ~ -- ~ ~ O v•- -y m _ O ___-- ~ _ ~ ~ ~ ~~~ ~ a -~Q ~ - -_ ~ _ ,, Q ~ ~ a ~ _ _ ~ ~ ~ ~ __ _ _„ ~ O zw Q ~ J J N Ln ~ ,Y ~ O J ~ ~ ~ ~ Z p o O _ _ __----- _;~ p ~ ~ r- Q a ~ ~~ • = ~ m ~ J O V ~ ~~ M Q ~ ~ O ~ ~ ~ ~ Q r ' V ~ ORIGINAL Closest in POOL '. _ .~~ £a~ ~` Closest A roach: Reference Well: 1J-105 w 04 Plan Offset Well: 1J-14 "> Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. TVD E + /W - 180° Comments Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance POOL Min Distance (239.84 ft) in POOL (239.84 ft) in POOL (7092 - 11724.07 MD) (7092 - 11724.07 MD) fo 1J-14 (6400 - 7462 to 1J-105 (wp04) Plan 239.84 11275 89.09 176.14 3681.918 5941786.5 563354.8 4247.973 MD) 7467.89 71.72 127.01 3803.9 5941780.3 563148.4 3518.38 (6400 - 7462 MD) Closest A roach: Reference Well: 1J-105 w 04 Plan Offset Well: 1J-118 Coords. - Coords. - ASP ASP 3-b ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Mtn. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments POOL Min Distance (1207.74 ft) in POOL +~~ ~ POOL Min Distance (1207.74 ff) in POOL (7092 - 11724.07 MD) (7092 - 11724.07 MD) to 1J-118 (7151 - fo 1J-105 (wp04) Plan 1207.74 7092.04 78 179.32 3552.994 5945947.2 563124.4 85.5859 14698 MD) 7129.43 78.2 358.27 3482.58 5947114.6 563426 -1351.64 (7151 - 14698 MD) Closest A roach: Reference Well: 1J-105 w 04 Plan Offset Well: 1J-103 Coords. - Coords. - ASP ASP 3•D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /W - 180° Comments Depth Incl. An le TRUE Azi. ND E + /W _ 180° Comments POOL Min Distance (1231.57 ft) in POOL ~~ ~ ~yJ -, POOL Min Distance (1231.57 ft) in POOL (7092 - 11724.07 MD) (7092 - 11724.07 MD) to 1J-103 (5990 - to 1J-105 (wp04) Plan 1231.57 7300 78.35 179.29 3596.197 5945743.8 563128.4 288.9945 11272.02 MD) 6440.96 81.2 179.19 3573.88 5945713.5 561897.4 348.69 (5990 - 11272.02 MD) POOL Summary Template.xls 2/23/2007 9:45 AM C L.~ ~~ V ~ 20" 94.0 x 34" Insulated Conductor, K-55, set at+/• 80' 70-3/4" x 47/2" Wellhead, 5,000 psi _~ Tubing, 4.7/2", 12.8#, IBTM, Spacial Drift to +/- 500' 110-314";BBA, BTC Shoe set, 3293' MD, 2250' TVD `'~ Tubing String ~ 47/2" 72.BM, L-80, IB II 3.958" ID, 3.933" Drift ~ 5.112" X 7•Sr8" ZXP Llnsr~ \A i Top Pecker wl Hold 4.73" Dowtls 3.875" DB Nipple, for Possible SSSV, +/- 500' GLM, Camco KBMG, 41/7' X t" GLM, Camta KBMG, 41/2" X 1" CMD Sliding Sleeve, w/ 3.81" DB Nipple, +/- 1 Jt above eeala 4.1 n" X 7-SIS" Seal res Model'B'HOOK Hancer 3.88~~ S-1n" X 7•SJB" ZXP Liner 1 Pad« wl Hdd Downs Lateral Entrv Module (LEM( Assembly t__-- s-trs" X 73r8" ZXP Llnar Top Pager with Mold Downs Casing Seelbora Receptada 4.75" I D OMenBng Pro81e Automatic Alignment o1 LEM Poshlve Latching Collet Indcates Comact Location Seal Bore for Laterel leolatlon • 3.88" ID '~ Access Window Poehlve Letard Access Vla Thru•Tubing Dlverter Seal Bore for Lateral Isolation • 3.88" ID IsolaBon Seal Asembly 4.75" Seal OD 3.875" Seal ID 20' Caring S-Ibore Receptacle, 20' Lengal \ateral Entry Module(LEM) •~-sand Window x1.7097 MD, 3862' TvD 'D' Sand Lateral 4.1n" 11.&M L-s0 SloHsd Payzone ECP Liner Every Othr Joint 1 , 4.112" Guide Shoe Seal ConocoPhillips West Sak 7-5/8" Injector 1J-105 Tri-Lateral Completion Entry Module(LEM) Window MD, 3728• TVD 'B' Sand Lateral a-1 n° 11.811 L-eo slot7ed ayz •ECP Liner Every Othr Joint x 7-s/e° ' Tieback Slaew muleshoe 4.717' 126#~bin3.582" DB 3.873" DM , 3.ese°ID '_ s•1 n^ x 7.91@" z~CP ~ Liner Top ParJcer whh Hold Dowitf"! ~. a•7n°x s° Liner Hanger I Packer Assembly et~~ Flex Lo +/-7540'MD ~ Liner Hang«\` / Casing Sealbore RebapTar 2a Length ~- Seal Ase~rnh~y 4.75" Seel OD rwr 7-5/8" 29.7# CBs me.arnagh..mos.rnbdoam.mn.yndh.r.proda~.doralrrlm,ad,b~.nororbp.n,b.mbrm«hy at~8815'MD, Ny mNne Nwronk r meehenlal, bdudlnq phdacopying, reeonlrry, or ty vy IdamYbn sleeps and ntrlevN system now knovm r heraNly InverdM, wllheN wr1aM WrmYebn hvm BYV Nughn bc. 111101rtf Baker Oil Tools As Planned With Diverters and Isolation Latent Acc-s Dlverbr Lateral Iwlatlon DNartar GS Running Tod String Inamlled Inatallad (3.00" Latrel DMR) (2.s0" ID Mdnbon DrHt) 'G8' Prenle r« Cdl Canned« i ~ ; ~RUndnglRstdeNng ti (7.00' Leng[h) ~ I ~ ~, ~ Snap In/8nap Out Bad Pnseun Valw ' f PosMw Locating ~ (1ba LsngM) collet i j Latarolladubn" t-Flaw-Thru BwlvN Swi. I (726' Length) f Cabral dvertr I Hydrsullc Ramp Dkeonnect (1 fi0'Length) laolrtlan/Mdnbon~~f ! ` . dvutr Sleaw ' ' GBB er P 1.60' Length) LrteN I-latbn ~'~ 8.86n Approx. SMb j OAL- f I ~ may ba nqulred in hghty dwlaled ' i 1&8' Divartr Lan th 0 16.B BIesw Length WsppHa one lB apprezlwigdll• Guide Shoe 41/2" Liner Shoe, 11.6!1, L-80 BTC Set ~ 77565' MD, 3634' TVD 41 n" 11,8# L-80 Slotted Liner Every 01her Joint 41n" Eccentric J (Guide Shoe -d i ssr_ _ _ =a,`•~ r ~r~-l',~~~:~ 47/2" C _t^_ =~1i~.-----`~.i...,J~: Set Eauioment Specifications 41/2" X 7-5/8" HOOK Hanger Malnbore DMt 5.32" Malnbore Dr1ft, with dwrter: 4.83" Lateral Dr1fL no dNerter or LEM: 3.88" Lateral Drift, w/ dlwrtar, no LEM: 3.88" Lat«allMalnbore Dlverter OD: 8.75" 41/2" Lateral Entry Module Melnboro Drift: 3.83" Malnbore Drift, wl leolatlon sleeve: 2.50" Lateral DMfL wl toll dlverter: 3,00" OD of D Wert« an d SI save: +r- 3.89" DNerter and Sleeve Length: +l• 18.5' Shoe, 71.6N, L-80 BTC '24' MD, 3850' TVD ~~ l~- ADS (84 deg) o.oni.: `~ WM Bea 7.50" Ta•INrN ComplNbn • YQi "': FWruvy 77, Y007 a""' Muc O. (cud ~~ 41/2" Liner Shoe, 11.BN, L-80 BTC i-117' Tieback Slesvs Set ~ 11521' MD, 3562' TVD bent muleshoe • • r: • SHARON K. ALLSUP-DRAKE 1174 CONOCOPHILLIPS ATO 1530 ~f ~p ~j ANCHORAGE AK 99501 DATE v~ ' `'"'rum 6-1551/441 PAY TO THE ~~.1 ~ /~ ~(rf1 ~ ~~ µ-r J-7C~ Q //~ ~C~ ORDER OF lil I ~ ~"' W / v~_ /yam o ,p, f ~ /G+- I~O~--__dDLLARS LJ ~,~ m ~.~ JPMorganChaSe~ j valid up To 5000oouars JPMorgan Chase Bank, N.A. Columbus, OH MEMO --- ~~'~~~~-- ~'-`~~ -- --~ ~:044L155LL~:528747L90792711'~L74 • TRANSMITTAL LETTER CHECKLIST WEL>J irANIE ~~,CG( /.~ /DS~ PTn# ZD'?-~ O Z~ ®evelopment '~ Service Exploratory Stratigraphic Vest Yon-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter ' CHECK I ADD-ONS TEXT FOR APPROVAL LETTER Vb'HAT { (OPTIONS) i APPLIES G I ~ ~^ I MliLTI LATERAL i The permit is for a new wellbore segment of existing (If last two digits b ' ;API ~ well in I Permit No. , API No. ~0- - - ' I er num ,' between 60-69) are Production should continue to be reported as a function of the original AP[ number stated above. PLOT HOLE In accordance with 20 AAC 25.005(f), a!! records, data and togs i ~ ~ acquired for the pilot hole must be clearly differentiated in both ' i I well name ( PH) and API number ~ ~ ~ (~0- - -_~ from records, data and logs ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC ~ EXCEPTION 125.055. Approval to perforate and produce / infect is contingent ~ upon issuance of a conservation order approving a spacing I ~ exception. assumes the ~ i ~ liability of any protest to the spacing exception that may occur. ~ ;DRY D[TCH ;All dry ditch sample sets submitted to the Commission must be in ; SAMPLE I no greater than 30' sample intervals from below the permafrost or i I I from where samples are first caught and !0' sample intervals j ' ,through target zones. ' ' ;Please note the following special condition of this permi*_: Non-Conventional production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data ,' j on water quality and quantity. 1Comnany Name) must contact the , { 'Commission to obtain advance approval of such water well testing i ~ 'program. ~ Rev: U2~i06 C " jody~transmittal_checklist • • m o a~ ~ c N ~ ~ : N• ~o ~ - c ~ 'o a , ~ c y, a ~ Q a ~ , , ~ i a ~~ c ~: 3 ~ ~ ~ O' ~ a~ ul ~a m .n. m. C N ~ N c ~, y ro p, rn: q ro I ~ m' ~ ~ , t`0 O) ~ O. J, m: Q O C p, ~ ~ ~ ~ ~ ~ ~ ~ ~ w~ , : ~ ~ ~ ro ~~ ~ T ~ ~: ~ .~ ~ N. ~ 3. ~ ~~ `O~ ~ W. O. w. X, y~ V, a, ~ c, O w ~ a 3 ~ ~ N r ~ N, ro, ~ _, i . ~ m' a~' i ~ E rn c ~, ro. v, c. ro. d, c. •~ c. N ._ ~ ro, m ~ ~ ~ d O O- ~: ~, ~ ~, ~: F-: ~ a ~ M: ~~ ~: $ t a , ~ O m e >' a ro, O. m uj, ~ 0 0, rn rn Y ~ ~ N . Y u m N~ m. ro, U O, ro ~~ ro 4 a N ~ 1 C O O : . l, ~~ ~ ~ ~ ~ M• N• ~ O, - U: 4 N. ~ . O~ dl~ p. c P ~ ¢ t O O O ~ N: ~ c, O~ O: -I , /l: C. : ' ' ~ ~ ~ ~, O: ~ ~: „N_,~ _ L~ . N, O Y1 ro ~~ o'i ro c ~ ~ ~ ~ a ~ ~~ ~ a ~ ~ ~n: ar ~~ c. of a ro~ ~ a ~, ' N p:. , N. ~ ~~ ~ , a' 'C .. N. C p. "O T N ~ « ~ N U ~: Q N a C C: ro, ¢ N 3 c: ~ X ~, ~ U. a ro, a ~ ro ci r-., d, o. c. '~ c. ~: c. Y. ~ ~: ~ v ,n~ ,~: ~ ~ ~ ~ ~: ~ . , ~ ~: ~ ~: t, r: ~: ro, a zi ~ ~ O w a~ m ~ ~ - o rn a. ro ¢, N ~ N X- o ~ ' w' I ', '~ ' a M N. N N. t/h y, N, N, b1~ N t~ N. fps N, N~ N~ N~ UA N, N. N, N. N~ N, N N N~ N, tq, y~ N, N. ¢ Un N. ¢, VD N O ~ O, Ub N; N~ N, ~ ¢, tA: N, N~ N~ y N, N, N ~ N~ N~ , N, N, N ~ Vn N O, N, N~ N~ N, N. ¢~ ¢, ¢, , >' >-, >-, >- ~, ~ >-, >-, ~ ~, >- >-, ~ ~, ~, >-, Z >- Z ~, Z Z. >- }•, Z, ?~ }~, >-, >- , >-, } } Z, } } } Z, z, Z T ~ ~ ~ Lam.: ~ ~ ~ ~ ~ ro ~ ~ ~ C ~ ~ ~ ~ , ~ U ~ ~ O' . : ~ , ~ , ..+ G -: , ~ ~, ~: : ~ ~ v' ~ ~ ~ A _ O i ~ v i ~ ~: ` p, C' - i ~ ~ ~' m. 3. ~ 3. o - ~ ~, ~ 'O Y ~ c. O • ~ ro: Z, «' : I ~ a N, : a~: ~: _ ~ Z. ~ N. 1 ' a ro' fn ~~I I Z ro ~ ~~ N W ~ Q' ~f ~~ ~ > ~ N. p. N i O: j N. O a ~ I ~ ~ : C : ~ ~ ~ j Q "B. O X41 •~ N ~ U ~~ ~ ~ ~: Q ro: - f0: ~ ~ ~ U C :~. ' I ~ ~ O ~ '~~ W ~ ~ O : . ~ ~ ty~ O i~ Vl: V O ' ~ I W ~ ~ O. N. 3 '"' C' ~, •~ .N: ` C 'a: N ~ p N~ O 7 ~ ~ ~~ N C C V7 - ro C >:' 3 O: N. ' ~,. ~ _ ~ ~ ~ Ci3 c ~ a`> , >' O~ a~ m `~ ~ O ~ ~° °' M: ° ~: 0 U a : ° N, 'o' . E v , O - ~ '~ .~ Q. ~ r~' ~.: °o O ~ - O: N, ~ n N p, ~ I U = t rn ~ N ro ~, 3 ~ o (~ c vs ~: ots c a i N, ° ; o o „ °, ¢ m' ro' m' m Y I Z ~ v o c ~ .o o ro ,c v ro d a _. ~ ~ o c ro m. o, o, o rn m - ~ d t, c. ~ m. ~ c p ~ ~ ~ E E - v 'O. C C E ro. N O M ~, C 3' c, N. ~ F- ~, C O o1S c. d ~' c m, „L_,' O' ~ N t ~ a ~, ¢ ` ; o "- o c ° O v ~ °, v ro ~ v, c o o ¢ o' a ~ v U °' ro m a ~ ~ °' ~ a o m 3' o ro >' N ~ T Y to ~ I g a ~ S O ~ ~ C T O 7 7 ~ . ~ ro ~ _ Y a: f0 ~ O O . c O ~~ ro ~ ~ Q . ro~ N i T O ~ ~. ~ Y ~ ~ a~ . ~ 4 ' c ~ c. p, . r a o r o r m c' ro ~, a~ ' , rn,' a -_ `0~ ~ c, `. n ~, ' Z' o '~ •_ ~' ~ . Q 3 0. a ar a 3' t m' ' 3 a 3. ~I ~ ~, ' c , ~, ro v :.° : ~ n n a~ m ~ . ~ m ro v E: ~' a i ~' ° ° ~ :? c~ ~; M ro' y. r, ~ U o ~ ~ ~ o m ~ o a ~ m o, o a a a c , w •~, 3 ' a' 3 a~ ~ a~ .. ' ~ ~ o . ~ 3 a m o v ro ur _ °~ o rn j o a~ 2 ~ d - o ~ o o ~ c > ~ ' o ~ 'Y ' ' ° ro ~ a~, ' - n a c, ~ U ° ~ a. ~ c : ' n ro. o ~' ~ ° L n m. ° ro n a ° i ~ ~ u°i a~ ~' N a ~ i ~ a ~. °' ° a :? ~? a ro' y rn ~, ~ -o f4 o o ~ v _ 3 ~ o =i v a i: c m. E. c o o. v 4 .N 3 `° c° .~? ro ._ y ~ "~ ~.: ro rn f ro ~ ca c ~o: ` Y ~ ur O •~ ~ f >, ' ~ . m ~' _ ° c ' ti ~ y o., ~- o. ; a~ O m ~ ~ ~ <o c' fl. a ~ ~ >' ui s s~ n 3~ c, ~°~ rn c o c~ or a' a r c c ro~ ; ~ ~ a~ a ~ o' 3 r- ~ o' ~' a~~ a?' >, ~ a> i ii. U c°' ' - v' y v m ~°' m U' ro ~ o r, . ~ r, u ' c . ° N a a o .y ~' t 3 ~ ~ °O ~ ~ ° ~ .Q, c m c c ~ , O m ~ ~ `° ro . c v c , 3~ ~ m . c°' o ro ro' v' ro - '_ ' ~ v ` m ro o o. m ~ c: o, . o. ro ° ro. c H Z ~ c' 3, c i c i' v ~' ~' o o ~ ~' ~ ~ vi v' > °' o o _ v :: a; m w a E, __ c. . . ~: ~ , : ~ ~ O'i ~ a~ ° o _o o' ~ ~ > a~ o ~ o. o ~ ~ . :. 3 rn c =' v ~ ~ •~ rn ro, m 3. N, m a • ' ~' ~ J UI ~ ~~ .~ ar a~ a~: ~~ a i~ a~ a~ ~ ~ c~ ~~ 3 ~ c c ~°~ F- H H~ 'u -i: aai ` a°i, ? '~ a~ d o ~ a v, ~ ~. ~°~ .~~ ~~: c Y ~ a ~ ~ ~ ~ ~' in ~ O O a a U ~: Q a z° U sip U ~ U U Q; ~ ¢: ~ o m' m' U ~; ~ ~'' ri o in cn U U , , , , , ro W a Q c- N M V ~ CO I~ O W Q1 ~ N ~ M ~ V .- ~ t0 ~ ~ f~ ~ 00 ~ m ~ 0 N ~- N N N M N tt N LL) N O N ~ W O N N N O ~ M M N M~ M M M ~ CO M M I~ 00 M M O M U .. _ .. - _ __. _ _H C Y ~ Q ~ ~ O ~ y 0 ~ N O i+ O W ~ ~` N ~ '', 0~ W O N N ~ _ M ~ _N N a' ~ ...~ O N a~3 N ~ '. ~ d 4` ,' ~ Q9 J ~ O ~ w ~ ~ a a ~~ a ~ a `o U N .C a c ro Y ro >fq `^~` V .0.. ~ M O ~ (~~ _{ rn° c O 0 .~ ~ C • .~ W o U ~, ~ ~ p ~~ a~ U c O m y O N ~ Q C~ J Well !-iistory 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 minding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ! ~ 1J105o04052007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 25 19:57:53 2007 Reel Header Service name .............LISTPE Date. ...................07/06/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................07/06/25 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: 1J-105 API NUMBER: 500292334600 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 25-JUN-07 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: w-0004912996 w-0004912996 w-0004912996 LOGGING ENGINEER: S. GREENE S. GREENE 5. GREENE OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 5 JOB NUMBER: w-0004912996 LOGGING ENGINEER: R. REPLOGLE OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2186 FEL: 2432 FWL: Page 1 ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1J105004052007SSN.txt OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 3387.0 7.625 8838.0 i 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) EXITING THE 1J-105 PB1 WELLBORE AT 7071'MD/3593'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4,5 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (G P). 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 1-5 REPRESENT WELL 1J-105 WITH API#: 50-029-23346-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11735'MD/3822'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.......07/06/25 Page 2 1.7105004052007SSN.txt Maximum Physical Record..65535 File Type. .. .........LO Previous File Name.......STSLI6.000 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM FET R PX ROP S 1 clipped curves; all bit runs merged. .5000 START DEPTH 3351.0 3371.0 3371.0 3371.0 3371.0 3371.0 3396.5 STOP DEPTH 11678.0 11685.0 11685.0 11685.0 11685.0 11685.0 11735.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 3351.0 3 7071.5 4 8843.0 5 9658.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7071.0 8843.0 9658.0 11735.0 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 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 Page 3 • 171050040520075SN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3351 11735 7543 16769 3351 11735 RPD MWD OHMM 1.21 2000 22.163 16629 3371 11685 RPM MWD OHMM 2.45 2000 18.1758 16629 3371 11685 RPS MWD OHMM 0.46 2000 14.3627 16629 3371 11685 RPX MWD OHMM 0.84 2000 13.967 16629 3371 11685 FET MWD HOUR 0.19 136.62 1.91276 16629 3371 11685 GR MWD API 19.07 161.75 68.9768 16655 3351 11678 ROP MWD FT/H 0.29 1464.34 169.987 16678 3396.5 11735 First Reading For Entire File..........3351 Last Reading For Entire File...........11735 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/06/25 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.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3351.0 7071.0 RPD 3371.0 7071.0 RPM 3371.0 7071.0 RPX 3371.0 7071.0 RPS 3371.0. 7071.0 FET 3371.0 7071.0 oP 3396.5 7071.0 $ LOG HEADER DATA DATE LOGGED: 27-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 4 17105004052007SSN.txt TD DRILLER (FT): 7071.0 TOP LOG INTERVAL (FT): 3396.0 BOTTOM LOG INTERVAL (FT): 7071.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.2 MAXIMUM ANGLE: 82,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3387.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.070 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT; -2.800 63.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction............ ...Down Optical log depth units...........Feet Data. Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Page 5 • 171050040520075SN.txt First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3351 7071 5211 7441 3351 7071 RPD MWD020 OHMM 3.64 2000 21.2179 7401 3371 7071 RPM MWD020 OHMM 4.31 2000 15.4362 7401 3371 7071 RPS MWD020 OHMM 0.46 201.6 13.1711 7401 3371 7071 RPX MWD020 OHMM 0.84 174.92 12.5591 7401 3371 7071 FET MWD020 HOUR 0.19 136.62 1.62178 7401 3371 7071 GR MWD020 API 19.07 161.75 63.5015 7441 3351 7071 ROP MWD020 FT/H 0.83 706.16 184.483 7350 3396.5 7071 First Reading For Entire File..........3351 Last Reading For Entire File...........7071 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 7071.5 8788.0 FET 7071.5 8788.0 ROP 7071.5 8843.0 GR 7071.5 8796.0 RPM 7071.5 8788.0 RPD 7071.5 8788.0 RPS 7071.5 8788.0 LOG HEADER DATA DATE LOGGED: 29-MAR-07 SOFTWARE Page 6 • SURFACE SOFTWARE DOWNHOLE SOFTWARE DATA TYPE (MEMORY O 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 VENDOR TOOL CODE DGR EWR4 17105004052007SSN.txt VERSION: Insite VERSION: 74.11 R REAL-TIME): Memory 8843.0 7071.0 8843.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ...0 77.5 89.3 ~ 1 LJ TOOL NUMBER 134745 121079 9.875 3387.0 Polymer 9.10 58.0 9.5 300 4.8 7.000 63.0 5.070 89.6 6.500 63.0 2.800 63.0 Name Service order units size Nsam Rep code offset channel .DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 Page 7 • 171050040520075SN.txt 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 7071.5 8843 7957.25 3544 7071.5 8843 RPD MWD030 OHMM 5.2 86.3 12.6587 3434 7071.5 8788 RPM MWD030 OHMM 4.75 80.67 11.6942 3434 7071.5 8788 RPS MWD030 OHMM 4.56 82.51 11.3277 3434 7071.5 8788 RPX MWD030 OHMM 4.42 85.08 10.7813 3434 7071.5 8788 FET MWD030 HOUR 0.22 23.5 0.848171 3434 7071.5 8788 GR MWD030 API 37.12 111.35 81.1178 3450 7071.5 8796 ROP MWD030 FT/H 0.29 1464.34 174.537 3544 7071.5 8843 First Reading For Entire File..........7071.5 Last Reading For Entire File.......... ..8843 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 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 RPS 8788.5 9608.5 FET 8788.5 9608.5 RPM 8788.5 9608.5 RPx 8788.5 9608.5 RPD 8788.5 9608.5 GR 8796.5 9601.5 OP 8843.5 9658.0 $ Page 8 • 17105004052007SSN.txt LOG HEADER DATA DATE LOGGED: 03-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9658.0 TOP LOG INTERVAL (FT): 8843.0 BOTTOM LOG INTERVAL (FT): 9658.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.1 MAXIMUM ANGLE: 91.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8838.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 63.0 MUD PH: 1.3 MUD CHLORIDES (PPM): 32000 FLUID LOSS (C3): 8.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 96.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Page 9 ~ ! 17105004052007SSN.txt RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMN 4 1 68 12 4 RPX MwD040 OHMN 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 8788.5 9658 9223.25 1740 8788.5 9658 RPD MWD040 OHMM 1.21 2000 60.4914 1641 8788.5 9608.5 RPM MWD040 OHMM 2.45 2000 49.3548 1641 8788.5 9608.5 RPS MWD040 OHMN 6.77 2000 21.9011 1641 8788.5 9608.5 RPX MWD040 OHMN 4.73 2000 21.8861 1641 8788.5 9608.5 FET MWD040 HOUR 0.19 94.74 7.4156 1641 8788.5 9608.5 GR MWD040 API 37.55 94.76 66.5668 1611 8796.5 9601.5 ROP MWD040 FT/H 0.8 284.45 153.059 1630 8843.5 9658 First Reading For Entire File..........8788.5 Last Reading For Entire File...........9658 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File TyE~e ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSL26.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9602.0 11678.0 RPM 9609.0 11685.0 RPx 9609.0 11685.0 RPS 9609.0 11685.0 RPD 9609.0 11685.0 FET 9609.0 11685.0 Page 10 • • 171050040520075SN.txt ROP 9658.5 11735.0 LOG HEADER DATA DATE LOGGED: 05-APR-07 SOFTWARE .SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11735.0 TOP LOG INTERVAL (FT): 9658.0 BOTTOM LOG INTERVAL (FT): 11735.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.0 MAXIMUM ANGLE: 97.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 wR4 Electromag Resis. 4 159436 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8838.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 74.0 MUD PH: 1.8 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 107.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Page 11 • 1]105004052007SSN.txt Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMN 4 1 68 12 4 RPx MWD050 OHMN 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9602 11735 10668.5 4267 9602 11735 RPD MwD050 OHMM 6.49 32.29 16.5612 4153 9609 11685 RPM MwD050 OHMM 5.61 35.83 16.0976 4153 9609 11685 RPS MWD050 OHMN 5.25 38.05 16.0172 4153 9609 11685 RPx MWD050 OHMN 5 43.61 15.981 4153 9609 11685 FET MwD050 HOUR 0.22 17.29 1.13721 4153 9609 11685 GR MWD050 API 43.8 117.12 69.6359 4153 9602 11678 ROP MWD050 FT/H 0.5 263.99 147.098 4154 9658.5 11735 First Reading For Entire File..........9602 Last Reading For Entire File...........11735 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/06/25 Origin ...................STS Tape Name...... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/06/25 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services scientific Technical services Page 12 Physical EOF Physical EOF End Of LIS File • 17105004052007SSN.txt Page 13 • ~ 1J105PB1o0327200755N.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 25 16:23:19 2007 Reel Header Service name .............LISTPE Date . ...................07/06/25 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical Services Tape Header Service name .............LISTPE Date . ............ .....07/06/25 Origin ...................STS Tape Name...... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services 1J-105 PB1 500292334670 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-JUN-07 MWD RUN 2 w-0004912996 5. GREENE G. WHITLOCK 35 11N l0E 2186 2432 MSL 0) 109.00 81.00 Page 1 V =Cai 2 o'3-~Ua~" ~ 1~3i5 • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J105PB1003272007SSN.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 3387.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE 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). THIS RUN WAS TERMINATED AFTER IT WAS DISCOVERED THAT THE MOTOR HAD TWISTED OFF. 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-105 PB1 WITH API#: 50-029-23346-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7473'MD/3659'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.......07/06/25 Maximum Physical Record..65535 File Type. ...........LO Previous File~Name.......STSLI6.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 2 i FILE SUMMARY 1.7105P61o03272007SSN.txt PBU TOOL CODE START DEPTH STOP DEPTH GR 3351.0 7426.5 RPD 3371.0 7419.0 RPM 3371.0 7419.0 RPS 3371.0 7419.0 RPX 3371.0 7419.0 FET 3371.0 7419.0 ROP 3396.5 7473.0 ~~ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3351.0 7473.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3351 7473 5412 8245 3351 7473 RPD MWD OHMM 3.64 2000 20.2838 8097 3371 7419 RPM MWD OHMM 4.31 2000 14.9274 8097 3371 7419 RPS MWD OHMM 0.46 201.6 12.8362 8097 3371 7419 RPx MWD OHMM 0.84 174.92 12.2537 8097 3371 7419 FET MWD HOUR 0.19 136.62 1.55469 8097 3371 7419 GR MwD API 19.07 161.75 65.9562 8152 3351 7426.5 ROP MWD FT/H 0.83 706.16 179.418 8154 3396.5 7473 First Reading For Entire File..........3351 Page 3 • 17105P61o03272007SSN.txt Last Reading For Entire File...........7473 File Trailer Service name... .......STSLIB.001 service sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/06/25 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.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.001 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 3351.0 7426.5 RPD 3371.0 7419.0 RPM 3371.0 7419.0 RPS 3371.0 7419.0 RPx 3371.0 7419.0 FET 3371.0 7419.0 ROP 3396.5 7473.0 LOG HEADER DATA DATE LOGGED: 27-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7473.0 TOP LOG INTERVAL (FT): 3396.0 BOTTOM LOG INTERVAL (FT): 7473.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.2 MAXIMUM ANGLE: 82.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 121079 Page 4 • i 1~105PB1003272007SSN.txt BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3387.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.070 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .. ......0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3351 7473 5412 8245 3351 7473 RPD MWD020 OHMM 3.64 2000 20.2838 8097 3371 7419 RPM MWD020 OHMM 4.31 2000 14.9274 8097 337.1 7419 RPS MWD020 OHMM 0.46 201.6 12.8362 8097 3371 7419 RPX MWD020 OHMM 0.84 .174.92 12.2537 8097 3371 7419 FET MWD020 HOUR 0.19 136.62 1.55469 8097 3371 7419 GR MWD020 API 19.07 161.75 65.9562 8152 3351 7426.5 ROP MWD020 FT/H 0.83 706.16 179.418 8154 3396.5 7473 Page 5 1~105P61o03272007SSN.txt First Reading For Entire File..........3351 Last Reading For Entire File...........7473 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name........... .LISTPE Date . ...................07/06/25 0rigin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comment5 .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................07/06/25 Origin.......... .......STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 6
