The URL can be used to link to this page

Home My WebLink About206-067Originated: Delivered to:9-Dec-24 Alaska Oil & Gas Conservation Commiss 09Dec24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1R-03A 50-029-21406-01-00 200-021 Kuparuk River WL IPROF FINAL FIELD 8-Nov-24 3S-718 50-103-20884-00-00 224-034 Kuparuk River WL TTiX PPROF FINAL FIELD 20-Nov-24 2B-11 50-029-21089-00-00 184-035 Kuparuk River WL IPROF FINAL FIELD 22-Nov-24 3S-617 50-103-20864-00-00 223-085 Kuparuk River WL IPROF FINAL FIELD 30-Nov-24 3M-22 50-029-21740-00-00 187-067 Kuparuk River WL LDL FINAL FIELD 2-Dec-24 1J-156 50-029-23311-00-00 206-067 Kuparuk River WL IPROF FINAL FIELD 2-Dec-24 2H-11 50-103-20052-00-00 185-261 Kuparuk River WL IPROF FINAL FIELD 4-Dec-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39843 T39844 T39845 T39846 T39847 T39848 T39849 1J-156 50-029-23311-00-00 206-067 Kuparuk River WL IPROF FINAL FIELD 2-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.10 08:20:31 -09'00' 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-156 KUPARUK RIV U WSAK 1J-156 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-156 50-029-23311-00-00 206-067-0 W SPT 3410 2060670 1500 577 577 567 564 655 656 656 656 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-156 Inspection Date: Tubing OA Packer Depth 1190 2000 1950 1940IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509111704 BBL Pumped:0.6 BBL Returned:0.6 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:11:19 -08'00' K,Ck )J-LG-(- f-'-(t (- f-''i D - 2, 0&06r Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, April 26, 2020 12:32 PM To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF7&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F Subject: LPP/SSV Returned to Service on Well 1J-156 Jim, The low pressure pilot (I -PP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 4/26/2020, as the injection pressure increased above the -PP setpoint after a sustained injection period. The well is currently injecting 1200 BWPD at 165 psi wellhead pressure. -- The -PP had been defeated on 12/24/2019, after the well slowly lost its wellhead injection pressure overnight. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 Regg, James B (CED) IN 2b(-()(,7cr From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, December 24, 2019 8:50 AMuC To: Regg, James B(CED)Z4�( I Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt Subject: LPP/SSV Defeated on CPA] Well 1J-156 on 12/24/2019 Jim, The low pressure pilot (I -PP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was defeated today, 12/24/2019, after the well slowly lost its wellhead injection pressure overnight. The well is currently injecting at 1150 BWPD with a wellhead pressure of 89 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. Thanks you, Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 C<�gGt IT -15G Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophilIips.com> Sent: Saturday, November 30, 2019 1:02 PM�'�c2 lZlz1(Q To: Regg, James B (CED) Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1&2 Ops Supt; CPF1 Ops Supv Subject: LPP/SSV Returned to service on CPAI Well 1J-156 on 11/30/2019 Jim, The low pressure pilot (LPP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was returned to service today, 11/30/2019. The well had been operating with the LPP defeated since 11/29/2019, but the wellhead pressure has built enough to satisfy the 100 -psi setting on the low pressure pilot. The well is currenting injecting 1050 barrels of seawater per day at 140 psig wellhead injection pressure. This notification is in accordance with "Administrative Approval No. CO 406B.001" Please let me know if you have any questions. Evan Reilly for Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, November 29, 2019 4:52 PM�� To: Regg, James B (CED) 6 Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1&2 Ops Supt; CPF1 Ops Supv Subject: LPP/SSV Defeated on CPAI Well 1J-156 on 11/29/2019 Jim, The low pressure pilot (LPP) on well SJ -156 (PTD# 206-067, 206-068, 206-069) was defeated today, 11/29/2019. The well's surface safety valve tripped as designed on declining wellhead pressure following a recent conformance treatment early this morning. The well was brought back online with the LPP defeated. The pilot was tagged and its status was recorded in the "Facility Defeated Safety Device Log". Operations has lowered the LPP setting to 100 prig but have NOT returned it to service today as the well is currenting injecting 1050 barrels of seawater per day at 110 psig wellhead injection pressure. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Evan Reilly for Toon Changklungdee /Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 Keuc !J"-ls6 Regg, James B (CED) 2060hIo From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, November 16, 2019 9:35 AM To: Regg, James B (CED) Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK West Sak Prod Engr Subject: LPP/SSV Returned to Service on CPAI well 1J-156 on 11/16/2019 Jim, The low pressure pilot (LPP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was returned to service and removed from the "Facility Defeated Safety Device Log" on 11/10/2019,, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 730 BWPD at 350 psi wellhead pressure. The LPP had been defeated on 11/10/2019 after the well lost its injection pressure post a reservoir conformance job. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 P 066M7o Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, November 10, 2019 3:46 PM II Jt,4. j To: l Regg, James B (CED) ( ` 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 Defeated on CPAI Well 1J-156 on 11/10/2019 Jim, The low pressure pilot (I -PP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was defeated today, 11/10/2019, after the well continues to lose wellhead injection pressure following a reservoir conformance job. The well is currently injecting at 315 BWPD with a wellhead pressure of 65 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 -PP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Danila Shutemov WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 Imo( l�-l5� Regg, James B (CED) From: NSK West Sak Prod Engr <n1638@conocophi Ilips.com> Sent: Tuesday, September 24, 2019 9:55 AM '\``L 1,'3610 To: Regg, James B (CED) \ I Cc: Autry, Sydney; Mowrey, Andrew F; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv, CPF1 &2 Ops Supt Subject: LPP/SSV Returned to Service on CPAI well 1J-156 on 9/23/2019 Jim, The low pressure pilot (LPP) on well IJ -156 (PTD# 206-067, 206-068, 206-069) was returned to service and removed from the "Facility Defeated Safety Device Log" yesterday, 5/23/2019, after the well was shut in following a monitoring period. The LPP had been defeated on 6/2/2019 after the well was brought online following a reservoir conformance job. 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 / Danila Shutemov WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 Kf-f,1 I I Regg, James B (CED) From: NSK West Salk Prod Engr <n1638@conocophiIli ps.com> Sent: Sunday, June 2, 2019 2:39 PM To: Regg, James B (CED) Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt Subject: LPP/S5V Defeated on CPAI Well 1J-156 on 6/2/2019 Jim, The low pressure pilot (LPP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was defeated today, 6/2/2019, after the well was brought online following a reservoir conformance job. The well is currently injecting at 495 BWPD with a wellhead pressure of 22 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the Ll - "Facility "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 WELL LO TRANSM/TTAL PRGAcTiVE DIACINosTIC SERVICES, INC. To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: 1) Injection Pm�l- 2) Signed Print Name: 2016©67 30815 ProActive Diagnostic Services, Inc. RECEIVED E'vE® Attn: Diane Williams P� 130 West International Airport Road MAY 21 2019 Suite C p,( -)GCC Anchorage, AK 99518 /� Pdsanchoraae(a memorvloo.com !'v nn A — 4 n A. ncn 50-029-23311-00 Date: U LM 1 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEaMEMORYLOGCOM WEBSITE: WWW.MEMORYLOGCOM D V\ hives Mast mplateFdes\Templaks\Mtibution\Tl minalShttfs conomphiMps_Trensmitd,s Iciet� 15'- (st, PT -t 2l7�CXo7� Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Saturday, April 6, 2019 9:55 AM To: Regg, James B (DOA) Cc: NSK Optimization Engr; CPF1 Ops Supv; CPF1&2 Ops Supt; CPF1 DS Lead Techs; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI Well 1J-156 Jim, The low pressure pilot (LPP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 4/6/2019, after diagnostic wellwork was completed and the well was shut-in. The LPP had been defeated on 3/27/2019 after the well was returned to service to perform wellwork. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-476Ofax Delivered to: rf 4/ AOGCC ATTN: Natural Resources Technician II �Y Alaska Oil&Gas Conservation Commision �•,y 333 W. 7th Ave, Suite 100 "%jj Anchorage, AK 99501 206007 t • TRANSMITTALDATE TRANSMITTAL so &WELL NAME 2B-10 1H-108 .. 9 50-029.21084-00EOSH-00034 50.029-23608-00 SERVICE ORDER E540-00064 FIELD NAME• KUPARUK RIVER KUPARUK RIVER • • WL WL1 • • IPROF IPROF r. FINAL FIELD FINAL FIELD Color r. TE 26 -Mar -19 27 -Mar -19 1 1H-105 U-156 1A•04A 50-029-20727.01 50.029-23311-00 50-029.20621-00 E540-00065 EA18-00008 E540.00068 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL IPROF IP Calipeper FINAL FIELD FINAL FIELD FINAL FIELD 28 -Mar -19 29 -Mar -19 4-Apr•19 1 1 1 3H-18 50-103-20095-00 EBLV-00002 KUPARUK RIVER WL IPROF FINAL FIELD 6 -Apr -19 1 2K-26 50-103.20126-00 EBLN•00004 KUPARUK RIVER WL Caliper FINAL FIELD 8 -Apr -19 1 10-06 50-029.21224-00 EBSI-00001 KUPARUK RIVER WL PPROF FINAL FIELD 10 -Apr -19 1 n 8 Name return via courier or sign/scan and email a copy Date and CPAI. Schlumberger -Private ATransmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Auditor - (Geu 1 J— 15(, Pi tb 2060670 Regg, James B (DOA) From: NSK West Salk Prod Engr <n1638@conocophillips.com> Sent: Wednesday, March 27, 2019 7:52 AM I(�� To: Regg, James B (DOA) Cc: CPF1 Ops Supv; CPF1 DS Lead Techs; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1 &2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI Well 1J-156 Jim, The low pressure pilot (LPP) on well 1J-156 (PTD# 206-067, 206-068, 206-069) was defeated today, 3/27/2019, in preparation for the upcoming wellwork. The well is currently injecting at a wellhead pressure of 10 psi and a rate of 1100 BWPD. 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 Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 THE STATE 01ALASKA GOVERNOR BILL WALKER Ron Phillips Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-156 Permit to Drill Number: 206-067 Sundry Number: 318-408 Dear Mr. Phillips: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat6/2-z tA� yPoerster Commissioner DATED this Z.7 day of September, 2018. RB�MsC f o I Zola STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RE E � V ED SEF 1 B 2010 vr-S 9112�f f e AOG 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Change Approved Program ❑ �Q Plug for Reddll El Perforate New Pool ❑ Re-enter Susp Well El Alter Casing Lf Other: lf4ol 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q - 206-067 3. Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510 50-029-23311-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1 J-156 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field/Pool(s): =1"-,^ ADL $66 25 O Z 63 Ku aruk River Field / it Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8281' - 3631' - 8281' 3631' 1,125 None None Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 108' 108' Surface 2739' 10.75" 2769' 2167' Production 6935' 7.625" 6961' 3626' D -Sand Liner LEM 190' 4.5" 5830' 3449' B -Sand Liner LEM 1 396' 4.5" 6198' 3509' A2 Liner 1 2115' 4.5" 8275' 3631' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7043-8197 3631-3633 4.5" L-80 5675' Packers and SSSV Type: Packer (Baker ZXP Liner top Paker) Packers and SSSV MD (ft) and TVD (ft): Packer (5640'/ 3410') SSSV (None) 12. Attachments: Proposal Summary ' Wellbore schematic � 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑✓ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/10/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑� GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: Sr. Wells Engineer Contact Email: Ron L.Phillio CCOP.com �_ � Contact Phone: 265-6312 Authorized Signature: t/W" Date: 9/17/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Ly' Mechanical Integrity Test Location Clearance ❑ Other: fjl7p 1-« f .754"U f -t5 L ` I � ZJ�bd /�h✓tvLa�' �Y<t�lri �"l✓ 7 CU / �`�� Post Initial Injection MIT Req'd? Yes t No ❑ �':/Qy� o S Spacing Exception Required? Yes ❑ No 0! Subsequent Form Required: APPROVED BY Approved by COMMISSIONER THE COMMISSION Date:9_ 7-19 l VTC ��z�/�� i� � ..,e *0- �� 9sueit Form and Form 10-403 Revised 4/2017 Approved appli O m the date of approval. ttachmenls in Duplicate 9C. $_ 9f►SjIB ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 17, 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Injector IJ - 156 (PTD# 206-067). CWestSak01 1 Poo I )a}.F B•9�/Sl/$ Kuparuk well 1J-156 was originally drilled and completed in 2006 as an `A/C' sand injector in Kuparuk. In May 2018 a tubing leak was found at 5,355' and in June 2018 a production casing leak was found at 5,347'-5,357'. The proposed workover scope for 1J-156 will include pulling the 4-1/2" completion from the Baker seal bore receptacle/ZXP liner top packer, patch the production casing leak and install a new 4-1/2" completion. This work will be performed by the Nabors 7ES. If you have any questions or require any further information, please contact me at 265-6312. Sincerely, Ron&C. Senior Wells Engineer CPAI Drilling and Wells IJ -156 Rig Workover (PTD #: 206-067) Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 4-1/2" completion, patch the production casing leak and install a new 4-1/2" completion. General Well info: Well Type: MPSP: Static BHP: Wellhead type/pressure rating: BOP configuration: MIT results: Production Engineer: Workover Engineer: Injector 1,125 psi using 0.1 psi/ft gradient 1,464 psi / 3,396' TVD (8.3 ppg EMW) measured on 06/18/2018 Gray Horz MB -222A, 5M psi top flange Annular / Pipe Rams / Blind Rams / Pipe Rams TBG leak at 5,355' MD Prod CSG leak at 5,347'-5,357' MD IC POT passed 4/15/2018 IC PPPOT Failed — 4/15/2018 TBG POT & PPPOT PASSED -4/15/2018 Sydney Autry (265-6813/ Sydney.Autry@ConocoPhillips.com) Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre -Rip Work 1. MIT testing. SBHP test. TBG and CSG PO tests. 2. FT LDS and grease tree valves. 3. Set a WRP plug and catcher at 5,682' (below seal assembly/above `D' LEM). 4. Pull DV from GLM#2 (circulation point) and leave DV in GLM#l. Workover Procedure 1. MIRU. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 2500 psi and annular to 2500 psi. 3. Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4. POOH laying down 4-1/2" tubing. 5. Perform a pFaduction casing clean out run to PeFferations 6. MU a test packer and verify casing leak depths. 7. MU a ras�lng scraper and tandem string mills to clean up the ID of the 7-5/8" production casing for the Metal Skin Patch. Rotate to clean up tight spots and area from 50' below to 50' above casing patch. 8. RU E -line and caliper production casing to verify casing is good to set Metal Skin patch. 9. MU, RIH and set Metal Skin patch from 5332' to 5372' MD. 10. PT 7-5/8" casing to 2500 psi. 11. RIH with 4-1/2" completion w/seals to sting into Baker SBR. 12. Space out and MU tubing hanger. Circulate corrosion inhibited fluid in the IA. Land the tubing hanger, RILDS. 13. PT the tubing. Hold pressure on tubing and pressure test IA and chart. Bleed tubing pressure quickly to shear the SOV. 14. Pull the landing joint, install BPV. 15. ND BOPE. NU tree. Pull BPV and install tree test plug. Test tree and pull test plug. 16. Freeze protect well with diesel. 17. RDMO. Post -Rip Work 1. Reset well house(s) and flowlines of adjacent wells. 2. RU Slickline. Pull SOV, ball & rod, run GLD then pull catcher and WRP plug. 3. Handoff to operations to put back on production. MetalSkin Openhole Liner Systems 5-1/2 x 7 in., 8 x 7-5/8 in., and 7-5/8 x 9-5/8 in Elastomarie seal elements. Expanding against parent casing, these elements p.,do cost -affective, reliable zonal isolation. Conventional and swallable seal elements are available. Expandable connectors. These connectorsared.wgned for use in — dogleg. up to 20° par 100 ft (30 m). Expandable liner bap pipe. Highly ductile and fracture -resistant material improves defect tolerance during expansion and lowers expansion pressure requirements, increasing reliability. Cone launcher. The cone launcher houses the expansion cone. Its short, compact design runs Nrough hi,hangle dogleg., reduces risk of differential sticking, and minimizes surge effect. Protection alaeve. This sleeve minimize. risk of damage to the system tluring run -m, especially when running through windows. F dantaldartl PDC tlrdlebkr float s etldetl reliabi(�ty during arades. Ssiatylcand Th:,.0-ch.as..mbl" eta latching mechanism allowhinner string to be connected to ther . Pump -down dart. This dart creates the primer, pressure seal required to initiate expansion. It has a proprietary nose with redundant alestamedc and metel-to- metal assts. 4-1)ebris barrier. To ensure that the system performs reliably, the debris barrier pnrrenta tlownhcie debris from entering the expansion system. Saal sup. The anal cup Cases a pasitivesealbetween the expansion system and expendable liner end provitles a beckpp ptassu...I to Me cone face seal. Hydraulically driven expansion. _ Hytlmulto pressure dim. the a sion cone up the line which minimises tension requirements on the work string. Solid body no. The shape of the - MetalSkin solid body can ie optimized for "so of exp union. MetalSkinOpenhole Solid Expandable Systems Expanding reliability Drill and Make up underream expandable hole section. liner, and hang in rotary. W Weafherfort weatherford.com Stab in work string and run to depth. (Pump cement Cone exits Drill out shoe if required) top of liner using if required and Drop dart and rig overpull. continue rig pressure up to operations. expand liner. 02014 We rhalmd. All rghte maerveU. Weatherford product, and aervicee are aubWt to the Company's standard temp an condition, available on request or at weatherford.cam. Far more info ra ion contact an autboriaed Weatherford notacenc ive. Unleaa rated otherano , trademarks and service nmdw herein are the property of Weatherford and Trey be registered in the United Slates and/or other countries. Weatherford products named herein trey be protected by one or me U.S, and/or foreign patents. Speaifaidions ere subject to change without notice. Weathedord call go products and aervkea g Accordance with the Wanda and condition set forth in the applhebl contact between Weatherford and the client. ConocoPhillips AIKSaa,lnc. WJI �O.Mun— _ IITSc aneGc-R[ HANGER. 32 - .umu..apaatt1,.. CONDUCTOR 28.1. NIFeur. as, SURFACE M.S.I. GAS UFT ])It GAS LIFT i's. SLEEVEL. SEES LOCATOR. SK SEK ASSY. 5.810 0 SAND LINER SLOTS gess" 105 I - _ SLOTS SLOTS. ].9]I Scmpore ARTuem _ _ FName FI SLOTS, i[ 500292331160 so..190 INJ 9607 ].902.76 12,963.0 Comment i I _ 9L0]5. E - Last WO: 31.2D 8/1212006 AnnotationDepNh(NKB) SLOTS gess" 105 I 1J -156L1 r 3 SLOTS. 11135410 0]0 Scmpore ARTuem _ _ FName FI i� SLOTS. 500292331160 11111 810 INJ SLOTS, 11.85]-1]065 0 SAID DNER. roansi IIi 596] KUP 1J -156L1 Well Attributes _ Max Angle & MD _TD _ Scmpore ARTuem _ _ FName FI YJeII Slalua InclUS Actetm(IIKBI- (°] 500292331160 WEST SAK INJ 9607 ].902.76 12,963.0 Comment Hati ppml Date A—panlon Suellen, KeGud" Rig Release Oala SSSV: NIPPLE !Annotation Last WO: 31.2D 8/1212006 AnnotationDepNh(NKB) .'in Dale Annotation Lase End By Encl Dale Last Tag: Rev Reason: REVISE 11.64 IDs osborl 5117/2013 Strings- C,N,ND npllon __ RN.NE Sln(NKCI ng ln.. TopSe1D.U,g $el DaNI, RVDI 51rnR U StrenS Sang, Top Rid j LINER _.._412 476 3cNpnan 6,238.3 12 925 1 ,407 6 3commem 1160 L80BTC FUSAND Liner Details Top Depm- mol Top Top@NBI LRB) II I. ") 62383 34972 9034 SLEEVE BAKER UP LINER SETTING SLEEVE 5.500 6,2904 3,497.1 89.89. XO BUSHING CROSSOVER BUSHING 3.930 12.865 a 3407.6 90.13 XO Reducing 4.5"x39' 3500 Perforations, &Slots "an III RIN USD) One TaP(XKIR on. LeARI (UK.) (XND) Zone Date (an Type Lamment 6,296.0 6,4250 3497.1 3,499.3 AS B, 1J156L17117/2006 32.0 SLOTS Allemating SlolteES01id pipe 6.125"x 25"x 32 spf l@ 4Crcumferenllal adjacent rows, 3" Centers staggered 18 deg., 3 ft. nansloaed ends 6,641.0. 6.9850 3499.1iI 3.466.2 WSB, 1J -156L' )1112006 320 SLOTS - 7,370.0 7,8020 3496.9 3502.61WE B, 1.1 156L1 711712006 32.0 SLOTS $062.0 84940 3489.1 3,4745 AS B. IJ -156L1 7/1712006 320 SLOTS 8.8340 9,3610 3,4684 3.464_0 WS 0, 1J -156L1 7117/2006 - 320 SLOTS 9,595.0 10.1050 34426 3431.2 WS B.1J-156L1 -711712006 - 32.0 SLOTS - 10,359.0 10.8706 3428.6 3631,2 WS B, 1J -156L1 7I17/2006 320 SLOTS 11,1110 11610.0. 3,4269 34049 WS B. 1J -156L1 7117/2006 320 -SLOTS 11,8570 12.8850 34022 3.407.6 WS B. 1J-15GL1 711712006 320 SLOTS Notes. General _. - & Safety _ — - ' End Dam Annoeuo..—-- 7/28/2006 NOTE: MULTI -LATERAL WELL: 1J-156(A-SANDT 1 J 156L 118 -SAND), iJ-156L2 (D -SAND) Mandrel Details Tap Depin Tap S.. (TVD] Ind N... } p(r NDI (nND) (') Male Madel { 1 32108 239606066 1 2 4,984 8 1222 65.42 CAMCO KBG-2-1R Pon OD Vave Land, Site TROR (Int Sen Type Type (a) Non) Ron Data C.—I 1 GAN LIFT DMv SIR 0000 009/262008 1 GAS LIFT DMV 5K-5 0.000 00�926@006LJ ConocoPPhillips AaSY.ai yeavacents miRlrtxab-111 SMnuuc-M ¢ANGER, �.al�LINGDETGR 211. NIPPLE, 497 SDRFACE e02, 76S GAS LIFT, _ 7211 GAS LIFT, ASel \ SLEE I 69WTDI'D iii ead. 159 SLOTS, 8.11]4.992 10,151-10857 SLOTS_ SLOTS, SLOTS, 11.6M1R 505 D-SWD LNER. tali 1 Tell, pact 12 565 KUP - — 1J -156L2 Zt li Attributes Top at Max An to & MD TD _ _ _ Wellbore923Ind.311 _ ._ _ _. -__ Well $talus Inch) M016K6) Ale 16601 WE TSA I 50029 2 3 311 61 WEST SAK BAKER'HR'SETTING SLEEVE INJ 94.22 6]]2.48 12,ard 12,5660 comment NlS)ppm) Data Aermselon End Oalc Kd-Brd(fil PIN Release Dale SSSV: NIPPLE PIG_ASLIFT Last WO: 3120 811212006 Annotton Depth TKR) End Dale Annotation Top ploth Blm 0RKe0 Last Mod By End Data Lad Ta9: _ Rev Reason: - REVISE 11.641 Ds DI _ 5/17/2013 Oasnistrings 0.125'x2 5' @ 4 cieumferential CasingD Ipllon 541593 $tong) I.. Top(XKBI GetD pll N—Set Depth ITVD) etong WL.. St ng Slring Top Thad O -SAND LINER 4112 _ 3476 5,859.8 12551.8 3,3305 11.60 _ 1-80 BTC Liner Details 320 SLOTS ].9120 84230 3,425.9 3405.5 WSD, 1J -156L2 1/24/2006 Top Depthv - — (Real.) Top at Rome. Topmilah8598 INKS) (9 Item s.. III comment 15750 5,859.8 3443.3 SLEEVE 89415LEEVE BAKER'HR'SETTING SLEEVE 5]50 3 5,9185 34437 8972 XO BUSHING CROSSOVER BUSHING 3 Perforations&Slots Ips)) Run Date ... —. f 3,2108 2396.060.66 PIG_ASLIFT Shot BK -5 TopLVD) An. nVDI i Dene Top ploth Blm 0RKe0 palld ARES Zone Date mp. Type Comment 5,9220 6669.0 34437 3,4367 WS D. 1J -156L2 7/2412006--32.0-SLOTS Allernatin9solidlsloAdd pipe - 0.125'x2 5' @ 4 cieumferential adjacent rows, 3'tappers staggered 18 deg, T non-sbaed ends 6.901 7,658.0 3432.9 3434.4 WS D, 1J-1561-2 7/4412006 320 SLOTS ].9120 84230 3,425.9 3405.5 WSD, 1J -156L2 1/24/2006 - 320 SLOTS 8,6830 9159.0 34010 3391.3 WS D. 1J -156L2 7/240006 32.0 SLOTS 9,4170 9892.0 33819 3368.8 WS D. 1J 15612 7/24/2006 32.0 SLOTS 10,1510 10970- 33633 3,3552 WS D. 11-156L2 17/24/2006 320 -SLOTS 10.9170 114280 3344.5 ._ 3,3379 WS D, 1J -156L2 7/24I2006 32.0 SLOTS ' 118540 125050 3.3355 3,332.4VJS D, 17.1561-2 ]/24/2008 320 SLOTS Notes: General&SafeiY_- _. _—_ _ -Erie 011, Ap5 7/2812006 NOTE: 6n 1J-1 MULTI -LATERAL WELL: 1J -156(A -SAND), 1J-1561-1 (B-sANDl, 1J-1561-2 (D -SANG) I Mandrel Details -T000eplF- - — — Top Pon s.. III OD sales Lama sive TRO Run N._ Top IHKB) (NKBI P) Make Madel Ili) 6ary Type Type (In) Ips)) Run Date f 3,2108 2396.060.66 PIG_ASLIFT DAY BK -5 0000 009260006 — 2 0.98481 3,22276542 CAMCO KBG-811 �1LGAS LIFE _ DMY BK -5 0009 0.091262006 20' 94.0# x 34' Insulated Conductor, K-55, set at+1- 80' 10-3/4" x 4lla' Wellhead, 5,000 psi ConocoPhillips I1 West Sak 7-5/8" Injector — 497'MD-3.875"DB Nipple 1J-156 3210' MD - GLM, Campo KSG-2, 4.112" X 1", 2395' TVD (60 deg) fj£ _ 4984'MD- GLM, Carrico KBG-2,4112"X1",3225'NO(BBdeg) * Tri -Lateral Completion 2769 -MID -10,114', 45.5#, BTC Shoe set, 2167' TVD Tubing String 4.1/2' 12,64, LA0, IBTM 3558' ID, 3.033" Drift / 5640' MD -5-12" X 7.518' ZXP Liner Too Packer w/ — 5594' MD -CMD Sliding Sleeve, w/ 3.81" DB Profile, 3401' TVD, (78 Deg) JH�585B' MD - Coal, Sealbore Receplack, 20' Length 5675 MD - Bottom of Seal Assembly 4.75' Seal OD 509CMD-412"X7418" / Model-B'HOOK Hander Beal Bore 360' ID 5684' MD - Lateral Entry Model. (LEM) D -sand Window 'D' Sand Lateral /at 5697' MD (78 deg) / 5810' MD - Paymne ECP 4-1a- 11.0 LA0 Slotted 3-12" Gold. Shoe 12551' MD -4.1/2' Liner Shoe, 11.6#,1.80 BTC, 3330' TVD %so' No - 5.12" Tieback Sleeve 5988' MD -Bottom of 412' bent muleshoe X830' MD -Bonom of Seal Assembly 4.75' Seal OD 5801 -MD 542'X7-5/6'•Z)(P Liner Top Packer wl Hold Downs Lateral Entry Module (LEM) Assembly - 5.112' X 7.54" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Prefile Automatic Alignment of LEM Positive Latching Collet a� Indicates Correct Location Seal Bore for Lateral Isolation -3.68" ID •\ Access Wintlow Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral - \ isolation -3.68"ID \Isolation Seal Asembly 4.75 Seal DD 3.575" Seal ID 5020' MD - Sealbore Re 6070' MD -4-112' X 7 -MB" Model W HOOK Harmer 4-112'• 12.60 Tubing 3.033' Drift 3.950" ID Lateral Entry Module(LEM) BSand Window at 6072' MD (80 deg) 'S' Sand Lateral / 6182' MD - Payson, ECP 4.12 11.60 L40 Slotted and Blank Liner vsks BAKER HUGHES Rukcr Oil "Pools As Completed Lateral Entry Module (LEM! With Diverters and Isolation Ltleral Appose chro er Mehl Radiation Divert GS Running Tool String Inched Installed 13.00- Lateral Data) (250' ID Malnbore Drift) 'W' Profile for call Connector /Running•Retrieving 11.00'LenglM1) Snap lmbnap Out r Back Preuure Valve •" Positiys Ldcating� se (160'Length)colla[ • Lateral lsoh8n" r Flow-Tnru 8wimel l Seals I1.2s•LenetM1J /Urged Demmer Rydraullc \ Rampso (150 Length) \ wooden/ M dr' DIberler Sl e I GS spear (I.5 Lee, Le tendn' 6.85R App 6.1.hH OAL' � doe.. iiPM1oi%nfRM1� 1a.s'Dr., n9IM1 1g3'Sleeve Length .rdeepePPOwtl nets. ' 6238MD -5.112" Tieback Sleeve 6283' MD -Bottom at 4-112'• bent muleshoe 6118' MD -1587 DB Nipple (05 deg) 5412" X LSIa" ZXP Liner Top Packer / witM1 Held Downs 1\\\/ 5-12' X TSIB' Flex Lock 6160'MD-Liner Hanged PackerLiner Hanger / Assembly 61sT MD -Casing Sealbo Receptacle, 20' Length m mer Xuenee 2aox This document ran, eat M mprMma or durbured. In wMn or In pan, m any fore orey any mwm dareamnlc or memariod.I adwarg phobcowina. morning, wby any lnfmmalbn s omen and realevel sy drem now, known or Mmaner Inveme4 w1maN wmlen peemaakn ham Bekx Xueb.5 NC. Guide Shoe 12925' MD - 4-112" Liner, 11.6#, L-80 BTC, 3407' TVD 619r MD - Bottom of Seal Assembly 4.75•' Seal Do 'A' Sand Lateral 4-112•' 1I N LAO Slotted and Blank Liner 4-112" Guide Shoe 6962' MD -74i/fl" 29.7# Casing, L-80, BTCM, 3626' TVD (86 deg) EE uipment Specifications 4-1/2" X 75/6" HOOK Hanger Malnbore Drift: 5.32" MalMorer Drift, with diverler: CST' Lateral Drift, no diverter or LEM: 3.88•' Lateral Drift, wl tliverter, no LEM: 3.88" LaterallMalnbDre Divener OD: 6.75" 4-1/2" Lateral Entry Module Malnbore Drift: 3.65" Member Drill w/ isolation sleeve: 2.50' Lateral Drift, w/ coil aiverter: 3.00'• DD Of Diameter and Sleeve:+1.3,09" Genstar and Sleeve Length:+I. 18.5' 8275' MD -4-112" Casing Shoe, 11.6#, LA0 BTC, 3522' TVD X•,wry Waal oak Tdlo- Td4akW Compledon-Inkaby'fNe.. IwtB, 2aaB Pwn N paw BlmX M,tnX 2 t q. I3-156 Rig Workover (PTD #: 206-067) Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 4-1/2" completion, patch the production casing leak and install a new 4-1/2 completion. General Well info: Well Type: MPSP: Static BHP: Wellhead type/pressure rating: BOP configuration: MIT results: Injector 1,125 psi using 0.1 psi/ft gradient 1,464 psi / 3,396' TVD (8.3 ppg EMW) me; Gray Horz MB -222A, 5M psi top flange Annular /Pipe Rams /Blind Rams /Pipe TBG leak at 5,355' MD Prod CSG leak at 5,347'-5,357' MD IC POT passed 4/15/2018 IC PPPOT Failed -4/15/2018 / TBG POT & PPPOT PASSED -4/15/2018 on 06/18/2018 Production Engineer: Sydney Autry (265-6813/ Sydney.Autry@ConocoPhillips.com) Workover Engineer: Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre -Rig Work 1. MIT testing. SBHP test. TBG and CSG PO tests. 2. FT LDS and grease tree valves. 3. Set a WRP plug and catcher at 5,682' (below seal assembly/above `D' LEM): - 4. Pull DV from GLM#2 (circulation point) and leave DV in GLM#L Workover Procedure 1. MIRU. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 2500 usi and annular to 2500 psi. 3. Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4. POOH laying down 4-1/2" tubing. 5. Perform a production casing clean out run to perforations. 6. RIH with 4-1/2" completion w/seals to sting into Baker SBR. 7. Space out and MU tubing hanger. Circulate corrosion inhibited fluid in the IA. Land the tubing hanger, RILDS. 8. PT the tubing. Hold pressure on tubing and pressure test IA and chart. Bleed tubing pressure quickly to shear the SOV. 9. Pull the landing joint, install BPV. 10. ND BOPE. NU tree. Pull BPV and install tree test plug. Test tree and pull test plug. 11. Freeze protect well with diesel. 12. RDMO. Post-Riz Work 1. Reset well house(s) and flowlines of adjacent wells. 2. RU Slickline. Pull SOV, ball & rod, run GLD then pull catcher and WRP plug. 3. Handoffto operations to put back on production. Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Wednesday, September 26, 2018 4:09 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 11-156(PTD 206-067, Sundry 318-408) RWO to patch PC leak and CO tubing Attachments: 11-156 General Procedure V2.doc; MetalSkin Openhole Expandable Systems- 5.5 X 7.0 -6.00 X 7.625- 7.625 X ....pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Sorry about that. Here is an updated General Procedure. I have updated steps 5-10 in the General Procedure and colored the changes blue. I also attached a W FT Metal Skin Patch data sheet. Please call or email if you have further questions. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO -13-1380 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, September 26, 2018 3:43 PM To: Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 1J-156(PTD 206-067, Sundry 318-408) RWO to patch PC leak and CO tubing Ron, I don't see in the procedure the step to run the patch or info on the patch? Did I miss its Please clarify. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 71h Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LoeopMalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law, If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or VictonaLoeooLalaska.aov . yof ?it* g • • ",_\\\Iy/,�sA THE STATE Alaska Oil and Gas F -t. OfA T A SIKIA Conservation Commission 1.1 ,Oritt TN 333 West Seventh Ave ue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3 72 r. ' Main: 907.279.1 33 OF elPs. Fax: 907.276.7 42 www.aogcc.alaska. ov Dusty Freeborn Well Integrity SupervisorIED y 1� � ConocoPhillips Alaska,Inc. �`� P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1J-156 Permit to Drill Number: 206-067 Sundry Number: 318-220 Dear Mr. Freeborn: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 81) ,-- Hollis S. French -11. Chair DATED this ( k day of June, 2018. RB DMS.11 JUN 12 2018 • • rW STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 3 0 2010 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A 1.Type of Request: Abandon H Plug Perforations LJ Fracture Stimulate LJ Repair Well ' • Operations shutd wn u Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool El Re-enter Susp Well CI Alter Casing I=1pad+vb,)7' C)'1 Other: u 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhilliDs Alaska, Inc. Exploratory ❑ Development ❑ 206-067 3.Address: ❑ Service Q• 6.API Number: Stratigraphic P. 0. Box 100360,Anchorage,Alaska 99510 50029233110006 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? t -5 0'1'3 • Will planned perforations require a spacing exception? Yes El No ElKRU 1 J-156 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025660,ADL0025661,ADL0025663- Kuparuk River Field/West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,281' - 3,631' ' 8281' 3631' 1156 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 2,739' 10.75 2,769' 2,167' Intermediate 6,935' 7.625 6,961' 3,626' Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7043-8197 3631-3633 4.500" L-80 5,646' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SBE Seal Assembly 5648'MD 3412'TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1-Jun-18 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑� • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Freeborn Contact Name: Dusty Freeborn Authorized Title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com Contact Phone: 907-659-7224 ~— Authorized Signature: Date: 2 5/�/�Vip�i , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 220 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test LJ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? YesNo ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: / '4 b APPROVED BY Approved by: La)5r-l_____ OMMISSIONER THE COMMISSION Date: 1p 1 t 1 he CJS � At��`sS�jot � � � e Wi sinf_�� Form 10-403 Revised 4/2017 Approved applicaORIJGJNOL'tI1 he date of approval. Attachments in Duplicate • ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 • 25th Day of May, 2018 Mr. Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 • Dear Commissioner French, • Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 1J-156 (PTD 206-067). The request is for approval to patch a tubing leak above the top packer. Please call Kelly Lyons, Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, • Dusty Freeborn Well Integrity Supervisor Attachments • • 11-156 (PTD#206-067) Proposal Summary 1J-156 (PTD#206-067)failed an MIT-IA. Diagnostics concluded that there is a tubing leak at 5355'. During the diagnostic process it appeared the CSV failed or the sliding sleeve was dislodged. A packer will be set below the tubing leak to complete the diagnostics and if integrity of the seal assembly, CMD, and production casing is proven that packer will be used as the lower anchor of the tubing patch. The tubing patch will be—23' mid-element to mid-element with the packers set at 5342'&5369'. The patch will be tested with an MIT-T and MIT-IA. If integrity is proven the well will be brought online and an • AOGCC witness test will be scheduled and a 10-404 submitted if all testing passes. 1. CTU Pull CSV from CMD at 5355' 2. Load T& IA with corrosion inhibited fluids 3. Obtain static bottom hole pressure. 4. Set lower packer at 5365'. 5. Set test tool in lower packer and perform CMIT-TxIA to 3000 psi. a. If CMIT-TxIA fails resume diagnostics for failure mechanism. b. If CMIT-TxIA passed pull test tool and proceed to step 6. 6. Install spacer pipe and upper packer at 5342'. 7. Set test tool and perform MIT-T to 2500 psi and MIT-IA to 3000 psi. a. If both tests pass, pull test tool and bring well online for AOGCC witnessed MIT-IA. Submit 10-404 if integrity of the patch is proven b. If either test fails trouble shoot failure mechanism and re-set patch as needed. • KUP 1NJ 1J-156 ArNw- ConocoPhillips A N..\\ Well Attributes & TO • •T . WellbW1 ore API/UField Name Wellbo Maxrcl.(*)AngleMD MD iftK13) Act Btm(ftKB) Alaska,Mc. '•,_ , 500292331100 WEST SAK INJ 8,281.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date ... SSSV:NIPPLE LastWO: 31.20 8/12/2006 Multiple Laterals-1J-156,5/22/2018 52642 AM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By .m....m...Last Tag: (masher HANGER;22A= `-.1171 Last Rev Reason - ' Annotation End Date Last Mod By Rev Reason:ADD CAT SV,FOUND THG LEAK 5/22/2018 condijw Casing Strings 4N-A,CONDUCTOR;2e.0.los.o.Aok-A".."-, -,-A-Ae.Caning . . ng Description OD(in) ID(in) Top(0(10) Set Depth ORB) Set Depth(ND)...WtlLen(I...Grade Top Thread NIPPLE;4972 .:-3E CONDUCTOR 20 19.124 28.0 108.0 108.0 94.00 H-40 WELDED Casing Description OD(In) (0(10) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread , SURFACE ' 10 3/4 9.950 30.2 2,768.7 2,167.0 45.50 L80 Buttress [ 1 Thread Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(L..Grade Top Thread SURFACE;30.2-2.763.7 " S INTERMEDIATE 75/8 6.875 26.2 6,961.3 3,625.5 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 GAS LIFT;3210.8 I D-SAND LINER LEM 41/2 3.958 5,640.2 5,830.4 3,449.0 )2.60 L-80 IBT Liner Details Nominal ID Top(19KS) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;4.884,8 5,640.2 3,410.4 78.39 PACKER BAKER ZXP LINER TOP PACKER 4.970 TUBING LEAK;5,355.0 i 5,659.2 3,414.3 78.37 SBR BAKER 190-47 CASING SEAL BORE RECEPTACLE 4.750 CAT SV;5,594.8 IL:-.' SLEEVE C;5,594.8 5,678.9 3,418.2 78.36 XO BUSHING CROSSOVER BUSHING 3.950 III 5,684.2 3,419.3 78.36 HANGER LEM ABOVE HOOK HANGER 3.980 5,694.4 3,421.4 78.36 HANGER LEM INSIDE HOOK HANGER 3.980 LOCATOR;5,646.4 5,785.4- 3,439.8 78.19 BENT JT 3.950 SEAL ASSY;5.648.1 " J 5,827.1 3,448.4 78.43 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 _. Casing Description 00(In) ID(in) Top(ft1(13) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-SAND LINER HH 41/2 3.476 5,694.3 5,908.8 3,463.2 11.60 L-80 BTC i Ili 1111 Liner Details ',II ri 'Fop(1105) Top(TVD)(1f013) Top Incl n Item Des Com Nominal ID l (in) •I 5,694.3 3,421.4 78.36 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 5.580 (INSIDE CSG) 5,711.0 3,424.7 78.35 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 3.990 (OUTSIDE CSG) or 5,810.7 3,445,0 78.13 ECP BAKER PAYZONE EXTERNAL CSG PACKER 3.930 il It OD(in)4112 ID(in)3.958 Top 5(780061).3 Set Depth(MB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • -a.ri CEIta-SMAnNDg DerINriEPR'LnEM 6,197.6 3,511.9 12.60 L-80 IBT D-SAND LINER LEM;5,640.2- 5,830.4 Liner Details Nominal ID 41Top(ftKB) Top(TVD)(ft0B) Top Inc!(1 Item Des Com (in) _ 5,801.3 3,443.1 78.15 PACKER ZXP LINER TOP PACKER 4.970 D-SAND LINER Hit 5.694.3- T 5,820.4 3,447.0 78.26 SBR BAKER 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,908.8 5,840.1 3,450,9 78.77 X0 BUSHING CROSSOVER BUSHING 3.950 • III III 6,059.6 3,487.9 80.57 HANGER LEM ABOVE HOOK HANGER 3.980 I i 1 i 11 6,070.4 3,489.7 80.56 HANGER LEM INSIDE HOOK HANGER CAMCO DB-6 NIPPLE 3.980 6,1182 3,497.6 80.21 NIPPLE 3.562 6,194.3 3,511.3 79.11 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread B-SAND LINER HH 4 1/2 3.476 6,070.3 6,283.0 3,527.3 11.60 L-80 BTC ..r. Il Liner Details Nominal ID EI[ it it Top(0013) Top(TVD)(ftKB) Top Inc](*) Item Des 6,070.3 3,489.6 80.56HANGER corn (in) BAKER MODEL B-1 HOOK HANHER FOR LEM 5.600 B-SAND UI/ER LEM;5,8012- it--°=-. (INSIDE CSG) 6,197.6 Maar MI 6,086.7 3,492.3 80.56 HANGER BAKER MODEL B-1 HOOK HANHER FOR LEM 5.600 . • I- (OUTSIDE 6,182.7 3,509.1 79.16 ECP (OUTSIDE CSG) BAKER PAYZONE EXTERNAL CASING PACKER 3.930 8-SAND LINER NH;6,070.3- Casing Description I"(i",1 1,21'"n1.476 Top(6ft1K6BL5iSet Depth(8ft2K7B)5.0 I Set Depth ITVD,63) 0...8.1Wt/Lelni(61.01 GL-r8adoe 1 TapThread6.283.0 A2 LINER , 1 Liner Details INTERMEDIATE;26.2-6,961.3 Nominal ID Top(ftKB) Top(1VD)(ftKB) Top Inc!n, Item Des Com (in) 6,160.5 3,505.0 79.52 PACKER 'C2'ZXP LINER TOP PACKER 5.750 SLOTS;7,043.0-7,130.0 6,177.9 3,508.2 7924 HANGER FLEXLOCK LINER HANGER 4.850 6,187.4 3,510.0 79.08 SBR BAKER 190-47 CASING SEAL BORE EXT. 4.750 SLOTS;7,344.0-7287.0 6,207.0 3,513.7 79.25 XO BUSHING CROSSOVER BUSHING 3.950 • SLOTS;7,431.0-7,474.0 ' Tubing Strings Tubing Description 1String Ma...ID(in) [Top(ftKB) I Set Depth(ft...rat Depth(TVD)I...WI(1h/ft) !Grade 1Top Connection TUBING 4112 3.958 22.4 5,674.7 3,417.4 12.60 L-80 SLOTS;7,517.0-7,581.0 Completion Details Top(TVD) Top Mc! Nominal SLOTS;7,602.0-7.642.0 Top(ftKB) (ftKB) (.) Item Des Com 10 1101 22.4 22.4 0.05 HANGER VETCO GRAY TUBING HANGER 4.909 SLOTS;7,685.0-7.728.0 4972 496.2 8.49 NIPPLE CAMCO'DB'NIPPLE w/3.875 NO GO PROFILE 3.875 5,594.8 3,401.2 78.01 SLEEVE-C BAKER CMD SLIDING SLEEVE w/CAMCO 3.81"DB PROFILE 3.810 SLOTS;7,771.0-7,814.0 (CLOSED 9/16/2011) , SLOTS;7,857.0-7,898.0 5,646.4 3,411.7 78.38 LOCATOR BAKER GBH-22 LOCATOR 3.875 , 5,648.1 3,412.0 78.38 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 SLOTS;7,941.0-7,984.0 ' . • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc] SLOTS;8,025.0-8,068.0 . Top(ftKB) (ftKB) n Des Com Run Date ID(In) 5,355.0 3,346.6 75.90 TUBING LEAK TUBING LEAK IDENTIFIED BY LDL 5/21/2018 3.958 SLOTS,8,111.0-8,155.0 , 5,594.8 3,401.2 78.01 CAT SV CAT SV SET WITH CTU 5/3/2018 0.000 SLOTS;8.197.0-8,241.0 1.. A2 LINER;6,160.5-8275.0 • KUP INJ • . 1J-156 ConocoPhillips 1w' Alaska,Inc. Multiple Laterals-1 J-156,5/2272018 5:26:46 AM Vertical schematic(actual) IIIIIMMIIIIMI HANGER;22.4= link ear Perforations&Slots =08.+0J.-^�`+'- ho NIPPLE;497.2 Dens Top(TVD) Btm(ND) (sot Shot Top(MB) Mtn(ftKB) (ftKB) (ftKB) Zone Date I Type Com 7,043.0 7,130.0 3,630.7 3,637.2 WS A2,1J-156 7/9/2006 32.0 SLOTS Alternating slotted/solid pipe 0.125"x 2.5"x 32 spf@ 4 SURFACE;30.2-2,768.7 0 Circumferential adjacent rows,3"Centers staggered GAS LIFT;32108 [ I- ed ndeg.,3 ft.non-slotted nds 7,344.0 7,387.0 3,661.5 3,664.1 WS A2,1J-156 7/9/2006 32.0 SLOTS GAS LIFT;4884.8 6, 7,431.0 7,474.0 3,665.4 3,665.5 WS A2,1J-156 7/9/2006 32.0 SLOTS 7,517.0 7,561.0 3,664.7 3,663.5 WS A2,1J-156 7/9/2006 32.0 SLOTS TUBING LEAK;5,355.0 7,602.0 7,642.0 3,662.1 3,661.6 WS A2,1J-156 7/9/2006 32.0 SLOTS CAT SV;5,594.9 7,685.0 7,728.0 3,661.6 3,660.3 WS A2,1.1-156 7/9/2006 32.0 SLOTS SLEEVE-C;5,594.8 '� 7,771.0 7,814.0 3,657.6 3,654.7 WS A2,1J-156 7/9/2006 32.0 SLOTS 7,857.0 7,898.0 3,652.1 3,649.8 WS A2,1J-156 7/9/2006 32.0 SLOTS If LOCATOR;5,646.4 7,941.13 7,984.0 3,647.6 3,645.2 WS A2,1J-156 7/9/2006 32.0 SLOTS SEAL ASSY;5,848.1 P 8,025.0 8,068.0 3,642.5 3,639.6 WS A2,1J-156 7/9/2006 32.0 SLOTS 8,111.0 8,155.0 3,637.0 3,634.7 WS A2,1J-156 7/9/2006 32.0 SLOTS til ;1 8,197.0 8,241.0 3,633.0 3,631.7 WS A2,1J-156 7/9/2006 32.0 SLOTS Mandrel Inserts `� st P I ati on Top(ND) Valve Latch Port Size TRO Run N Top(MB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1 3,210.8 2,395.9 1 GAS LIFT DMY BK-5 0.000 0.0 9/26/2006 2 4,984.8 3,225.5 CAMCO KBG-2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/26/2006 'a 1R C Notes:General&Safety End Date Annotation D-SAND LINER LEM;5,6402- 7/28/2006 NOTE:MULTI-LATERAL WELL:/J-156(A-SANDS),1J-156L1(B-SANDS),1J-156L2(D-SANDS) 5,830.4 2/8/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0REV ii D-SAND LINER HH;5,694.3-5,908.8 111, 1 II I 'I• fl i 8-SAND LINER LEM;5,801.3 ,) 6,197.6 I B-SAND LINER HH;6,070.3- z. 6,283.0 . `. I INTERMEDIATE;262-6,961.3 SLOTS;7,043.0-7,130.07—t SLOTS;7.344.0-7,387.0rl SLOTS;7.431.0-7,474.0—j SLOTS;7,517.0.7,561.0� SLOTS;7,602.0-7,642.0 SLOTS;7,685.0-7,728.0 L'— I % SLOTS;7,771.0-7,814.0e SLOTS;7,857.0-7,898.0 SLOTS;7,941.0-7,984.0 SLOTS;8,025.0-8,068.0 - SLOTS;8,111.0-8,155.0 SLOTS;8,197.0-8,241.0 A2 LINER;6,160.5-8.275.0- 41) Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday,April 16, 2018 12:11 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of failed MITIA 1J-156 (PTD 206-067)4-16-18 Attachments: 1J-156 schematic.pdf; 1J-156 90 day TIO plot 4-16-18.JPG Chris, West Sak water injector 1J-156 (PTD 206-067)failed an MITIA yesterday. The well was being prepped for upcoming 4-yr pad testing next month. The well has been shut in and freeze protected and will remain so until the leak can be identified and a repair implemented with proper paperwork submittal. Well intervention work with Eline/Slickline/coil etc will be pursued to identify the leak location and/or secure the well as needed. Please let us know if you have any questions or disagree with the plan forward. Attached is the 90 day TIO plot and schematic. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 1 8p • • a) ~ > p X f0 O p N W > - z °' D Z Q N L O +-� a Y Y 4- 73 ft ') aU +�V( > r (0 O v, a) t) 1111 a a) r0 T O (6 {., (6 L QItt ❑ L O Q w t a Cr CO ❑ Q O r r r• r- n r.. e~- ,_ r N a1 p Q p > > > > > > > > > > 0 E t -p OL N _t 0 0 0 0 0 0 O O O O O -a L w Z Z Z Z Z Z Z Z Z Z Z E CU 2 N 1— N M v N F 0o Wr - U O . L C Z 0 (13 p ,' N a Z a, v g O O +'O to O L 00 UU ❑ ❑ C:10 ❑ ❑ ❑ ❑ ❑ ❑ O a) "' L i•-•i ill LU J J J J J J J J J J J bA 4-- O y W W W W W W W W W W W •L F- LL LL LL LL LL LL LL LL LL LL LL a) U a) -O Q J J J J J J J J J J J O- > +, a) F- Q Q Q Q Q Q Q Q Q Q Qa) w C ,� "' Z v Q Z Z Z Z Z Z Z Z Z Z Z u ca a) O L CU O' LL LL LL LL LL LL LL LL LL LL LL CC -0 E > aC _ C g Q. t0 > a) 4. U _c O 4 U • tr z U E a<LT a) U a) rro. O c O ;,7 CO > U a) + rts v Q a) co ° °c a U ro d w O LL LL LL LL LL LL LL 34 ;te., L C ❑ t t O J O O O O LL O O Q� eJ m -- as = -Iaaaaxaa • Q a a 1- a () cia ♦b J Lu o is m °6 ¢ o PO Q v a fx .... r. Z> 1-.1 OJ �t,�/ W n�1 Y.1 W 0 &� aL re m3 acE333 � � 3333 �-+ 4 N o I I I W W W W W W W W W W W w > > > > > > > > > > > Z Y Y Y Y Y Y Y Y Y Y Y 0 R CC CL CL FY CL W C4 C4 CL IY Q Q Q Q Q Q Q Q Q Q Q L A a a a a a a a a a a a = o lea > > > > > > > > > > > @ a (� Y Y Y Y Y Y YYYYY O tiA O 0 cc X n 0 0 00 0 0 o v NO 0 v T0 K 0 0 0 0 0 0 N 0o 0 0 0 0 0 0 0 0 0 o y w x o 0 0 0 0 0 0 0 0 0 0 CD o O -o 00 00 00 n 0o co > r .. > > N N ❑ E rL 2 ❑ 2 2 > � _ ❑ ❑ ❑ ❑ ❑ o ❑ ❑ ❑ ❑ ❑ aQ c CO co O 0 0 0 1- 0 0 0 0 0 0 - OU 17 O LO 0 0 0 0 9'1' 0 0 0 0 - IX F CO a- � N000 . iiiili ! llt C vi M CO CO N 0 N 0 0 Nf) _ a CO 0 CO CO CO el el el e) CO a- N Ln N N M N M N M N ( I I IF CO - ,_ N a N N N c'.1 N N N N N N N N L L j: i',.Q O O1 co OI O O O OI Of Of R N N N O N N N N N N N O �' Otv 0 0 O O 0 0 0 O O O CD U O O O O O O O O U O O U ,o �' O O OiI L!1 C N N N N N N N N LA N to �' d OU O CC w Cn y U W Y pE I a) to ca ..+ •: W VI E E N N a Z 61 O Q Of N N a N C N rTo CU c i Y W VI 00 4) r Z ., i" M ., e- r C H aa; a) L c n' Q O N y�j a-- W N W ,- s- , N ,- e- N Z H O O LLO1 t n Co m O CID a. 3 ci 3 Co •: ar o 0 F- a a � F g/ . yy �� THE STATE Alaska Oil and Gas ti 4�� o fLAsKA Conservation Commission - 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER wh Main: 907.279.1433 ALASIljs' Fax: 907.276.7542 www.aogcc.alaska.gov Robert Christensen NSK Production Engineering Specialist SCANNED ELT I OM? ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-156 Permit to Drill Number: 206-067 Sundry Number: 316-353 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6il&gl°;°Lt4 Cathy P. oerster Chair DATED this Zath of July, 2016. RBDMS t-L- JUL 2 2 2016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 0 5 2016 APPLICATION FOR SUNDRY APPROVALS ( /L 20 AAC 25.280 AOGGC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r p r Operations shutdow n Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: WINJ to WAG F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc." Exploratory r Development r 206-0670 3.Address: Stratigraphic r Service pm6.API Number: P. O. Box 100360, Anchorage,Alaska 99510 50-029-23311-00^ 7. If perforating, lio 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No 1 KRU 1J-156 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025661;ADL025660;ADL025663 . Kuparuk River Field/West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8281 3631 " 8273' - 3630' ' 943 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20 108' 108' SURFACE 2739' 10 3/4 2769' 2167' INTERMEDIATE 6935' 7 5/8 6961' 3626' D-SAND LINER LEM 190' 4 1/2 5830' 3450' B-SAND LINER LEM 396' 4 1/2 6198' 3509' A2 LINER 2115' 4 1/2 8275' 3631' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:7043-8241 " 3631 -3666 4 1/2 L-80 5675 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=CAMCO'DB'NIPPLE w/3.875 NO GO PROFILE MD=497 TVD=496 PKR=BAKER ZXP LINER TOP PACKER MD=5640 TVD=3411 12.Attachments: Proposal Summary WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14.Estimated Date for 15. Well Status after proposed work: 07/20/16 OIL WINJ Suspended Commencing Operations: rr WDSPL r P r 16.Verbal Approval: Date: GAS r WAG 17, GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139Ca�conocophillips.com Title: NSK Production Engineering Specialist Signature 4.444 Date: /2,//Commission Use Only 0 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' \(.k. .-'36- Rug (.k.Rug Integrity r BOP Test r Mechanical Integrity Test cation Clearance r Other: Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No IV Subsequent Form Required: `G —40 of- RBDMS 1-1-- JUL 2 2 2016 APPROVED BY Approved by:(,),, _ COMMISSIONER THE COMMISSION Date: 7 _ _`/ L. l$1' .,>r,r;.6 S"14 7/ii(//t ad 7i114/p Sl(, 5d �' � ,�/ Submit Form and Form 10-403 Revised 11/2015 RIoe L li ALlid for 12 months from the date of approval. Attachments in Duplicate 0 • • RECEIVED J U L 0 5 2016 Robert Christensen/Darrell Humphrey Production Engineering Specialists. NIPV OG CC Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhil I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 July 2,2016 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert West Sak well 11J-156, 1J- 156L1, J- 156L1, & 1J-156L2 from Water Only Injection to Water Alternating Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1J-156, 1J-156L1, & 1J-156L2 (PTD#'s 206-0670, 206-0680, & 206-0690). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, ,/ irok __ Robert D. Christensen Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • • • 1J-156 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-156 (PTD# 206-0670) from Water Only Injection Service to EOR Water Alternating Gas Injection service. Area of Review: West Sak well 1J-156 was completed as a Water Only Injector on July 7, 2006 to provide injection support into the West Sak D, B, and A sands. Converting this well to a WAG injection well will provide enhanced recovery injection into the reservoir and increase the ultimate recovery of oil. This well will support existing producers 1 J- 152, 158, & 178. Area Map with Y4 mile radius around target injection zone(see attached): There are three wells which pentrate the Wsak interval within a 1/4 mile radius of 1J-156. Offset producer 1J- 152, and the production/injection pair 1J-180& 182. The additional wells (158, & 178) are provided to give a complete picture of the developement area. Mechanical Condition of Well to be Converted: The mechanical condition of Wsak well 1J-156 is good and is classified as a "Dual Casing -Trilateral"well. The injection tubing/casing annulus is isolated via a Baker ZXP Liner Top packer located at 5640' and (3411'tvd). Passed State-witnessed MIT-IA to 2010 psi was last performed on May 16th, 2014. • • 7 27Jun16 • ConocoPhillips Alaska, Inc. 1J-156 N 10-403 Sundry 0 0.15 0.3 0.45 0.6 Miles ADL025660 ADL025661 r \ 1J 1J-156 1J-152' / i / .. / 1J-158 ADL025662 =!'1J-152L2 ADL025663 1J-152L1 1J-156L2 / çLlb iii 1J-156 Open Interval III"" elm 1J-156L2 Open Interval 1J-156L1 Open Interval — 1J-156 Trajectory * Well Pad 1J-178 Q 1/4mi Radius 1J-156 ❑ 1/4mi Radius 1J-156L2 ■mL'3gb'Pfrum�ti ADL380058 In 1/4mi Radius 1J-156L1 —Well within 1/4mi Radius 1J-182L1 �■WestSak PA 1J-180L1 1J-180 1J-182 II:= KRU Boundary 0 CPAI Lease • • • E Ev '-° '¢ E E E,z •E n` i.30 o a i '2,2.',s' 3 3 3 3 3 .7a 1 E ocgE Y i Z 23:°,',2 Z Z 2.0 Z u 25 ' ¢ m P u 8 _ ¢ _ ¢ n E AN e; N a aw ao E u,4 w u v c m _ r 9 0 oN "° e c 3 m '°w w °° 3 w m m 0 4 [AtV4E fi 5 8: G ,v3 2 E gncp Dit!,- U o o : o m II `" n N N ^ m � m 11 7f, E t n E C a 11 E t n ° o o`o o`o -.T, 11- 0 8 n o w o 22 @,E @, E @@J E @,E QE 0 0 ,n EA 2 Yn$ . EAw l 0 0 ' ay o , o , ooo o ,C:_ ,t o,C o ,' C,C s ' o 22 '& ' d _w ` e / 51, to w !",, s E = LL ' U V U t H D p w V>G ry N 1E ry LIQ ry N N N CC gU O _ _ n _ O _ C t8p b C . M M ip a 0 H 0.... 9N azm m m m 0 Ts E E E s a o 3 :1 a a¢ W15 a D s a `o a " ,-- co 3 ,-. m F- c` - III o. L. ¢ n m Z9 P 3 a a a 0 0 0 0 0 0 m a a ' KUP 1J-156 ConocoPhilhps - Well Attributes Max Angle&MD TD Alaska. -.. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) carnmmnlips 500292331100 WEST SAK INJ 8,281.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date SSSV:NIPPLE Last WO: 31.20 8/12/2006 Well Conrp:Multiple Laterale-1.-156 51,7/2013 6 54:29 AM Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:REVISE 11.64 IDs osborl 5/9/2013 HANGER.22 Casing Strings Casing Description String 0... String ID...Top(kKB) Set Depth(1...Set Depth(TVD)...String Wt...String... String Top Thrd - - CONDUCTOR 20 19.124 28.0 108.0 108.0 94.00 H-40 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 30.2 2,768.7 2,167.0 45.50 L80 Buttress Thread CONDUCTOR, 28-1013 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth MD)...String Wt..String...String Top Thrd NIPPLE,497 - 4:e INTERMEDIATE 75/8 6.875 26.2 6,961.3 3,625.5 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 D-SAND LINER LEM 41/2 3.958 5,640.2 5,830.4 3,450.4 12.60 L-80 IBT Liner Details SURFACE, I L. Top Depth 30-2,769 (TVD) Top Incl Nonni... Top(ftKB) (KKR) El Item Description Comment ID(in) GAS LIFT, 5,640.2 3,410.7 78.54 PACKER BAKER ZXP LINER TOP PACKER 4.970 3,211 # 1 5,659.2 3,414.4 78.49 SBR BAKER 190-47 CASING SEAL BORE RECEPTACLE 4.750 GAS LIFT, 5,678.9 3,418.3 78.44 XO BUSHING CROSSOVER BUSHING 3.950 4•9B5 5,684.2 3,419.3 78.43 HANGER LEM ABOVE HOOK HANGER 3.980 5,694.4 3,421.4 78.41 HANGER LEM INSIDE HOOK HANGER 3.980 SLEEVE-C, 5,785.4 3,439.9 78.19 BENT JT 3.950 I e is 5,595 5,827.1 3,449.9 80.58 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 LOCATOR,_ v `� ' Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(IVO)...String Wt...String...String Top Thrd 5,546 MIK`i D-SAND LINER HH 4 1/2 3.476 5,694.4 5,908.8 3,463.2 11.60 L-80 BTC SEAL ASSY, 1�( 5,648 i Liner Details '. Top Depth (ND) Top Incl Nonni... Top(ftKB) (ftKB) (") Item Description Comment ID(in) 5,694.4 3,421.4 78.41 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM(INSIDE CSG) 5.580 5,711.0 3,424.7 78.37 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM(OUTSIDE CSG) 3.990 5,810.7 3,445.0 78.13 ECP BAKER PAYZONE EXTERNAL CSG PACKER 3.930 Casing Description String 0... String ID...Top(ftKB) Set Depth(1_.Set Depth(ND)...String Wt...String... String Top Thrd B-SAND LINER LEM 41/2 3.958 5,801.3 6,197.6 3,508.9 12.60 L-80 IBT Liner Details -, Top Depth (ND) Top Incl Nonni... Top(ftKB) (ftKB) F) Item Description Comment ID(in) D-SAND LINER 5801.3 3,443.1 78.15 PACKER ZXP LINER TOP PACKER 4.970 LEM, 5,640-5,830 5,820.4 3,448.8 80.58 SBR BAKER 109-47 CASING SEAL BORE RECEPTACLE 4.750 1-, 5,840.1 3,452.0 80.58 XO BUSHING CROSSOVER BUSHING 3.950 8,059.6 3,488.3 81.16 HANGER LEM ABOVE HOOK HANGER 3.980 D-SAND LINER •" 6,070.4 3,489.9 80.99 HANGER LEM INSIDE HOOK HANGER 3.980 5,654-5,90 6,118.2 3,495.9 78.23 NIPPLE CAMCO DB-6 NIPPLE 3.562 i 6,194.3 3,508.1 77.47 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd B-SAND LINER HH 41/2 3.476 6,070.3 6,283.0 3,527.3 11.60 L-80 BTC Liner Details Top Depth (ND) Top Incl Nomi... Top(ftKB) MB) I°) Item Description Comment ID(in) 6,070.3 3,489.8 80.99 HANGER BAKER MODEL B-1 HOOK HANHER FOR LEM(INSIDE CSG) 5.600 III -_ _, 6,086.7 3,492.4 80.72 HANGER BAKER MODEL B-1 HOOK HANHER FOR LEM(OUTSIDE CSG) 5.600 1111---i-I 6,182.7 3,509.1 78.97 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.930 Casing DescriptionString 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd 0-SAND LINER A2 LINER I 41/2 I 3.476 I 6,160.5 I 8,275.0 I 3,630.8 I 11.60 L-80 I BTC LEM. ... 5,801-8.198 aIII L Liner Details Top Depth ( ) Top Incl NOM... lop(MB) (RKB) (°) Item Description Comment ID(in) B-SAND LINER • 6,160.5 ND3,504.7 78.72 PACKER 'C2'ZXP LINER TOP PACKER 5.750 6,070.6,283 6,177.9 3,508.2 78.92 HANGER FLEXLOCK LINER HANGER 4.850 6,187.4 3,510.0 79.03 SBR BAKER 190-47 CASING SEAL BORE EXT. 4.750 NTERMEDIATE, 26-6.961 6,207.0 3,511.3 77.85 XO BUSHING CROSSOVER BUSHING 3.950 SLOTS. Tubing Strings 7.043'7.130 =' Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND).. String Wt..String.. String Top Thrd 11111 TUBING 41/2 3.958 22.4 5,674.7 3,417.5 12.60 L-80 7.344-738; 1 - - _ Completion Details I I Top Depth (ND) Top Incl Nomi... SLOTS,7A31-7,474 Ti il _= Top(ftKB) (kKB) 1°1 Item Description Comment ID(in) 22.4 22.4 0.00 HANGER VETCO GRAY TUBING HANGER 4.909 7snas6, - 91079, ___ i i _ 497.2 496.2 8.49 NIPPLE CAMCO DB'NIPPLE w/3.875 NO GO PROFILE 3.875 5,594.8 3,401,3 78.41 SLEEVE-C BAKER CMD SLIDING SLEEVE w/CAMCO 3.81"DB PROFILE 3.810 7,60 2 SL-7,OTS,642 - E, - (CLOSED 9/16/2011) - 5,646.4 3,411.9 78.52 LOCATOR BAKER GBH-22 LOCATOR 3.875 7,68S7D,ize - 5,648.1 3,412.2 78.52 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 7,771-7,8 SLOT14 S, _- 1 - 7,657-7, SLOTS, • - SLOTS, 7,941-7,984 SLOTS. Ss,_'.R 8,025-8.068 SLOTS. F g Mandrel Details 8,111-8,155 Top Depth Top Port (ND) Incl OD Valve Latch Sloe TRO Run N...Top(RKB) (ftKB) 11 Make Model lin) Sery Type Type ON (Psi) Run Date Com... SLOTS, 8,197-8,241 _ 1 3,210.8 2,396.0 60.66 1 GAS LIFT DMY BK-5 0.000 0.0 9/26/2006 A2 LINER, - . s,,s,a,z7s 2 4,984.8 3,2222.7 65.42 CAMCO KBG-2-1R 1 GAS LIFT DMY BK-5 0.000 0.0 9/26/2006 TD(1J-1S8),\ j L 8,281 �e ` s KUP • 1J-156 .., COnOCOPhillipS pi Alaska,Inc. KB-Grd(ft) Rig Release Date • Well Confi9.Multiple Laterals-1J-156,5/17/20136:54 29A L 31.20 8/12/2006 Schematic:-Actual HANGER,22 li ,r / Perforations&Slots Shot Top(TVD) etm(TVD) Dens Top(RKB)Btm(RKB) (7:31 (ftK3 Zone Date Den Type Comment CONDUCTOR, 7,043.0 7,130.0 3,630.8 3,634.0 WS A2,1J-156 7/9/2006 32.0 SLOTS Alternating slotted/solid pipe 0.125"x 28-108 1 2.5"x 32 spf @ 4 Circumferential NIPPLE,497 SI. adjacent rows,3"Centers staggered 18 deg.,3 ft.non-slotted ends 4 7,344.0 7,387.0 3,661.0 3,664.1 WS A2,1J-156 7/9/2006 32.0 SLOTS SURFACE, 7,431.0 7,474.0 3,664.9 3,665.5 WS A2,1J-156 7/9/2006 32.0 SLOTS 30-2.769 7,517.0 7,561.0 3,666.8 3,663.6 WS A2,1J-156 7/9/2006 32.0 SLOTS GAS LIFT, ' 7,602.0 7,642.0 3,657.8 3,661.0 WS A2,1J-156 7/9/2006 32.0 SLOTS ilft 3,211 II 7,685.0 7,728.0 3,664.2 3,660.7 WS A2,1J-156 7/9/2006 32.0 SLOTS 7,771.0 7,814.0 3,657.6 3,654.8 WS A2,1J-156 7/9/2006 32.0 SLOTS GAS LIFT, . 4.985 U 7,857.0 7,898.0 3,650.3 3,649.4 WS A2,1J-156 7/9/2006 32.0 SLOTS #r`: 7,941.0 7,984.0 3,647.6 3,644.9 WS A2,1J-156 7/9/2006 32.0 SLOTS ati SLEEVE-C, 5595 8,025.0 8,068.0 3,642.5 3,640.0 WS A2,1J-156 7/9/2006 32.0 SLOTS 4 8,111.0 8,155.0 3,637.0 3,634.9 WS A2,1J-156 7/9/2006 32.0 SLOTS LOCATOR, -' 8,197.0 8,241.0 3,633.0 3,631.7 WS A2,1J-156 7/9/2006 32.0 SLOTS SEAL ASSN, f Notes:General&Safety 648 MIMI End Date Annotation 7/28/2006 NOTE:MULTI-LATERAL WELL:1J-156(A-SANDS),1J-156L1(B-SANDS),1J-156L2(D-SANDS) 2/8/2011 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV D-SAND LINER LEM, 5,6405,830 il 11 i DSAND LINER • HH, 5,6945,909 I Ila IN B-SAND LINER ! LEM. 5.8015,198 ailli l B-SAND LINER HH, 6,070-6,283 / NTERMEDIATE, 26-6,961 SLOTS, -- --_ 7,0437,130 tlet - 7,344-7,387 SLOTS, I I SLOTS, 7,431-7.474 - g o 7,517-7,561 SLOTS, - i SLOTS, c 7,602-7,642 i`04 ^ 7,685LO7, STS, 728 7,771-7,814 - SLOTS, - ft 6 7857..898 SLOTS, 5 `e SLOTS, - 7,941-7,984 SLOTS, m - 8,025-8,068 SLOTS, 8,111-8,155 SLOTS, 8,197-8,241 I -_ A2 LINER, 6,161-8,275 TO(1J-156), _._.-.I I- 8281 8,281 • • faLA (J- (s-z, Z%,O 1 o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday,July 19, 2016 1:59 PM 1Ce14 i((1(k To: NSK West Sak Prod Engr; Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M Subject: LPP/SSV's returned to service on CPAI iJ wells Jim, The low pressure pilots(LPP) on the following wells were returned to service today, 7/19/16, after injection pressures increased above their pilot settings. 11-122 (PTD#207-070, 207-071, 207-072) 1J-127 (PTD#206-047, 206-048, 206-049) 1J-136 PTD#206-154,206-155) J-156(PTD#206-067, 206-068,206-069) The aforementioned wells have been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Notification will be sent when the remaining 1.1 water injector's LPP's are placed back in service. Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers SCOW JAN 1 1201E ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com From: NSK West Sak Prod Engr Sent: Sunday,July 17, 2016 7:57 AM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Op "upv<n2067@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com>; Sullivan, Michael<Mic.:el.Sullivan • conoco.hilli.s.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269 CP onoco.hilli.s.com>;Targac, Gary <Gary.Targac@conocophillips.com>; NSK Optimizat. Engr<n2046@conocophillips.com>; CPF1 DS Operators <n1275@conocophillips.com>; Stanley, Scott M cott.M.Stanley@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI 1.1 . ~ s Jim, 1 Regg, James B (DOA) (QOw_o l0 7 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, July 17, 2016 7:57 AM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI 1J wells Jim, The low pressure pilots (LPP) on the following wells were defeated today, 7/17/16, after water injection service was restored to drillsite 1J following the CPF-1 facility shut down. 1J-102 (PTD#206-110, 206-111,206-112) 11-118(PTD#206-176, 206-177, 206-178) 1J-122 (PTD#207-070,207-071, 207-072) SCANNED JAN 2 vaa 1J-127 (PTD#206-047, 206-048, 206-049) 1J-136 (PTD#206-154, 206-155) 1J-154 PTD#205-035,205-036, 205-0371 1J-156(PTD#206-067 206-068, 206-069) The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." All injectors are on water injection and stable with building wellhead injection pressures. The AOGCC will be notified when each well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638Pconocophillips.com 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the #ile. ~~ ~ - ~ ~1~ Well History File Identifier Organizing tdone) ~j Two-sided III ~I'IIt II I~) J! III ^ Rescan Needed II I II~~I~ I) I I II I III RESCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: /s/ Protect Proofing III 111111 IIIII II III BY: Maria Date: /s/ Scanning Preparation ~ x 30 = 1 ~.d + ~ =TOTAL PAGES j Count does not include cover sheet) BY: Maria Date: /s/ Production Scanning III 111111 IIIII II III Stage 7 Page Count from Scanned File: ~ (Count d oes include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ~ ~~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIII) IIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked I II I I' lll II I II' I II I 10!6!2005 Well History File Cover Page.doc • • Page 1 of 2 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638 @conocophillips.com] Sent: Tuesday, September 20, 2011 9:53 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist Subject: RE: RLPP /SSV defeated on multiple 1J West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the wells listed below have been returned to service on 9/20/2011 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure pressures and injection rates are also listed below. This pilot had been defeated on 9/16/2011 in accordance with "Administrative Approval No. CO 406B.001." The injection pressures has increased on the following wells so as to remain above 500 psi and the LPP /SSV function has been returned to normal. Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1J 156 (206- 06,206- 068,206 -069) 555 1095 1J-160 (207- 015,207- 016,207 - 017) 545 607 Please let me know if you have any questions. Jenn Gauer Y { Work - 907.265.6782 ; .� . R ss Mobile - 303.248.6641, , From: CP • od Engr Sent: Friday, Se. ber 16, 2011 6:44 PM To: 'tom.maundero) - ka.gov'; 'jim.regg @alaska.gov' Cc: CPF1 DS Lead Techs, •Fl Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Sei•, = ian; CPF1&2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on tiple 13 West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the followin• , ells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since Augu 7, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is record - • . the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 18 • • s on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injec Pressure (PSI) Injection Rate (BWPD) 1J-105 (207 - 027,207- 028,207 -029) 345 639 1J-118 (206- 176,206- 177,206 -178) 327 1020 1J-127 (206 - 047,206 -048, 206 -049) 337 934 1 J -154 (205 -036,205 -037) 369 623 1 J -160 (207 - 015,207 -016,207 -017) 352 568 9/20/2011 • Page 1 of Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Saturday, September 17, 2011 6:21 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: RE: RLPP /SSV defeated on 1J-156 West Sak injectors and returned to service for 1J-180 and 1J- 184: 17- Sept -2011 Tom and Jim, The low pressure pilot (LPP) on the following well was defeated on 09/17/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV has been tagged and the status is recorded in the "Facility Defeated Safety Device Log" since the wells is below 500 psi. As of 1800 hrs on 09/17/2011, wellhead injection pressure and injection rates are as follows for the well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) (1J156 (206 -067 206 - 068,206 -069) 437 899 The AOGCC will be notified when the injection pressure on this well has increased so as to remain above 500 psi and the LPP /SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 406B.001." The injection pressures has increased on the following wells so as to remain above 500 psi and the LPP /SSV function has been returned to normal. Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1J-180 (206- 150,206 -151) 555 471 1J-184 (206- 044,206 -045) 539 640 Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers ��,` n1269 @conocophillips.com - i r . 659 -7493 pager 659 -7000 765 •• CPF1 Prod Engr Sent: Fri.. •, - .tember 16, 2011 6:44 PM To: 'tom.maunder ...ov'; 'jim.regg @alaska.gov' Cc: CPF1 DS Lead Techs; C• - • Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; • : • is Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 13 We - ' 'ectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/ . ' e when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging face i •.ifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device : -" ince the 9/19/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 19, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile / Water Flow Log: 1J -156 Run Date: 5/16/2011 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 -156 Digital Data in DLIS /LAS format, Digital Log file, Interpretation Report S I" CD Rom 50- 029 - 23311 -00 Water Flow Log 1 Color Log 50- 029 - 23311 -00 Injection Profile Log 1 Color Log 50- 029 - 23311 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood t� �d 4. 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 3 c lk i l kfi l Signed: jL U MEMORANDUM To: Jim Regg ~~~ ~~ ~ ~ 1 a 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-156 KUPARUK RIV U WSAK 1J-156 Src: Inspector NON-CONFIDENTIAL CJ Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV U WSAK 1J-156 API Well Number: 50-029-23311-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100516142525 permit Number: 206-067-0 Inspection Date: 5/14/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _ Well ~1J-15 ype Inj. W T~7D ~ 3410 IA ~ 1147 P.T.D~ 2060670 TypeTCSt SPT Test psi ~ 1900 ~ QA 206 ~ -- ---- 1900 ~ 206 1890 1890 206 205 al aYRTST per, P .. Tubing 628 Interv 625 _ 623 I 620 ~I.- _ _ _ _ Notes: a4n, f e~~~• ~sl- ~S~X:~-; r ~°r k~~ Monday, May 24, 2010 Page 1 of 1 # • .~x ~. -,.~ ,.M~ : ~ ~ ~ r. ~~ ~ ~~ r . `~ z .,~. _ ~ ~~~~ ,~" ; ...~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE.. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc u ~J 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. ~r ~ /„~J FIELD /UNIT /PAD: Kuparuk /KRU / 1J ~ ~'1 ~(f DATE: 05/14/10 p(,lJ OPERATOR REP: Colee /Phillips - AES AOGCC REP: Bob Noble ~ ~ ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubing 657 656 655 654 Interval 4 P.T.D. 2061100 Type test P Test psi 1500 Casing 990 1,700 1,680 1,680 P/F P Notes: OA 165 205 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 Type test P Test psi 1500 Casing 1,098 1,800 1,780 1,780 P/F P Notes: OA 155 156 156 156 Well 1J-118 Type Inj. W TVD 3,599' Tubing 657 658 658 658 Interval 4 P.T.D. 2061760 Type test P Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OA 175 192 177 175 Well 1J-122 Type Inj. G TVD 3,684' Tubing 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casing 809 1,690 1,640 1,620 P/F P Notes: OA 141 214 174 156 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 ~~ 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 C"L. ~r1.. `'<;'..~.. _ ,. ~ Jar ,?; ~' s iii MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s J Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubin 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 1,866 .1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test .V/ 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 MEMORANDUM To: JimRegg \\~~~ ~(2~~~~ P.I. Supervisor ~ 6 FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-156 KUPARUK RIV U WSAK 1J-156 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~_ Comm Well Name: KUPARUK RIV U WSAK 1J-156 Insp Num: mitRCN090526114938 Rel Insp Num: API Well Number: 50-029-23311-00-00 Permit Number: 206-067-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-ls6 " Type Inj. W TVD 3410 IA 1290 1800 1790 ]790 P.T.D zo6o670" TypeTest SPT Test psi lsoo OA az9 azs az9 az9 Interval 4YRTST p~ P / Tubing 596 596 590 585 Notes: t: i `'! G. Ul~ Wednesday, May 27, 2009 Page 1 of 1 • • The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: October 15, 2008 RE: MWD Formation Evaluation Logs: 1J-156 1+L1PB L2 AK MW 4467716 ~-- ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-156+L1+L1PB1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23311-00,60,61,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23311-00,60,61,70 Digital Log Images ,, 1 CD Rom ~~,~f, 50-029-23311-00,60,61,70 ~~~ad~,~'~~~~~ ~`` '`t'~" PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3536 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: v ~~~ 1 ~ ~,cao~--o~`~ -~-rsy ~~1sa ,~~s-~ ~~ ~~~ ~ ~~ ~~°~ I~ ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~'~ :~'.::. Log Description 09/05/08 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 iJ-127 12096529 INJECTION PROFILE ~ - ~ 08/14/08 1 1 1 R-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE 08/17/08 1 1 1J-122 12066542 MEM INJECTION PROFILE / (~ 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE (Q 08/18/08 1 1 28-14 119966275 PRODUCTION PROFILE / ~(- r ~p 08/19/08 1 1 iJ-105 12066543 MEM INJECTION PROFILE 01(}'}- I(O 08/19/08 1 1 2E-12 11996653 SBHP SURVEY C.. ~ - ~ 08/21/08 1 1 iJ-156 12080419 INJECTION PROFILE ( 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q - f 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ( ` 08/22/08 1 1 2D-05 12080422 INJ PROF/LDL / ((p ~ 08/23/08 1 1 1H-11 12080423 PRODUCTION PROFILE (p 08/24/08 1 1 26-03A 11996656 PRODUCTION PROFILE / 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY ~ p~- <(p / 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / =- ~ $-Q 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE '^' Oa Glq 08/30/08 1 1 2E-13 12080431 SBHP SURVEY ~ - ~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. r • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~ SEA ~ w 20~~ Dear Mr. Maunder: ~.d~' a Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1 J-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 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1 J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 a ~ ~~ ~~ DATA SUBMITTAL COMPLIANCE REPORT ~~n 7/7/2008 ~~~ Permit to Drill 2060670 Well Name/No. KUPARUK RIV U WSAK 1J-156 Operator CONOCOPHILLIPS ALASKA INC ~/, `~~ MD 8281 TVD 3631 Completion Date 7/27/2006 Completion Status 1-OIL Current Status 1WINJ API No. 50-029-23311-00-00 REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name -~ (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / • Scale Media No Start Stop CH Received Comments ~Ftpt 14038 LIS Verification Open 8/22/2006 Cement Evaluation 5 Col 1 4000 6150 Case 7/25/2006 USIT, GR, Max Trac, CCL 10-Jul-2006 ~~D C Lis I 14038 Induction/Resistivity 2735 8215 Open 8/22/2006 GR, FET, ROP, Res - ~',~Je~g Production 5 Blu 1 100 6210 Case 9/15/2006 PPL WelTec Tractor !i Conveyance 6-Sep-2006 { D Asc ~ Directional Survey 0 8281 Open 11/9/2006 ~ ',~ Injection Profile 5 Blu 1 5550 6200 Case 4/20/2007 Injection Profile, Welltec Conveyance 15-Apr-2007 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMgTION Well Cored? Y rM\V Daily History Received? N Chips Received? ~'`t~ Formation Tops ~/ N Analysis `~P4- Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 7i7~zoos Permit to Drill 2060670 Well Name/No. KUPARUK RIV U WSAK 1J-156 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23311-00-00 MD 8281 ND 3631 Com tion Date 7/27/2006 Completion Status 1-OIL Current Status 1WINJ U Compliance Reviewed By: - __ _ Date: ~_~__ --- LPP/SSV returned to service o~-i56. LPP/SSV defeated on 1J-i36. ~ Page 1 of 2 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Saturday, April 12, 2008 9:29 AM To: NSK West Sak Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; Allsup-Drake, Sharon K; CPF1 DS Lead Techs; NSK Problem Weil Supv; Pierson, Chris R Subject: LPP/SSV returned to service on 1J-156. LPP/SSV defeated on 1J-136. Tom /Jim, The LPP/SSV function was returned to normal on 1J-156 (PTD # 2.06-067, 206-068, 206-069) on 4/10/08. The well is currently injecting 1782 bwpd at 554 psi well ea pressure. The LPP/SSV on 1J-136 (PTD # 206-154, 206-155) was defeated 4/11108 when the well was returned to production after a ~1 month shut in period (rig workover on an adjacent well). The LPP and SSV have been tagged and are recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 1458 bwpd at 451 psi wellhead pressure. Judging by the current wellhead pressure trend, I expect we will be able to return the LPP/SSV to service in ~1 week. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: {907) 659-7749 Email: n1638@ConocoPhillips.com From: NSK West Sak Prod Engr Sent: Monday, March 31, 2008 1:12 PM To: `tom.maunder@alaska.gov'; gim_regg@admin.state.ak.us' Cc: NSK West Sak Prod Engr; NSK Prod Engr Tecfi; Rodgers, lames T; CPFi Prod Supt; Alisup-Drake, Sharon K; CPFl DS Lead Techs; NSK Problem Well Supv; Pierson, Chris R Subject: West Sak Injector 17-156: Notii9cation of Defeated Low Pressure Pilot (LPP) Tom /Jim, This email is to notify the AOGCC that the West Sak Injector 1J-156 (PTD No.s 206-067, 206-068, 206-069) Low Pressure Pilot (LPP) is defeated as of 1/31/2008. This is in accordance with "Administrative Approval No. CO 4068.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". 4/12/2008 LPP/SSV returned to service on 1J-156. LPP/SSV defeated on 1J-136. • Page 2 of 2 The 1J-156 was shut in on 2112/2008, and restarted 3/31/2008. Current injection rate is 840 BWPD, injection pressure at the wellhead is 315 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Eric Hollar !Hai Hunt West yak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 4/12/2008 West Sak Injector 1J-156: Noti ication of Defeated Low Pressure Pilot~PP) Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Monday, March 31, 2008 1:12 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; Allsup- Drake, Sharon K; CPF1 DS Lead Techs; NSK Problem Well Supv; Pierson, Chris R Subject: West Sak Injector 1J-156: Notification of Defeated Low Pressure Pilot (LPP) Tom /Jim, This email is to notify the AOGCC that the West Sak Injector 1J-156 (PTD No.s 206-067, 206-068, 206-069) Low Pressure Pilot (LPP) is defeated as of 1/31/2008. This is in accordance with "Administrative Approval No. CO 4066.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". The 1J-156 was shut in on 2/12/2008, and restarted. 3/31/2008. Current injection. rate is 840 BWPD, injection pressure at the wellhead is 315 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, tnc. Phone 907-659-7061 Pager 907-659-7000 x836 3/31!2008 . Page 1 of 2 Regg, James B (DOA) ~ ~,~_~~~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, March 07, 2008 3:52 PM To: Regg, James B (DOA} Cc: NSK Problem Well Supv Subject: RE: 10-404 converting a well to injector without packer MD Attachments: 1C-20.pdf; 1J-102.pdf; 1J-156.pdf; 1J-170.pdf; 1J-127.pdf; 1J-184.pdf Jim, Here are the schematics of the motherbores for the list of wefts below. Let me know if you need any additional data or if the 10-404's need to be corrected and resubmitted. MJ Loveland ConocoPhillips Well integrity Project Supervisor 659-7043 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, March 03, 2008 1:58 PM To: NSK Problem Well Supv Ce: Fleckenstein, Robert J (DOA) Subject: FW: 10-404 converting a well to injector without packer MD Martin - West Sak wells have some unique approvals as you are no doubt aware. We discussed the exemption from packer requirements (20 AAC 25.200} - I am still looking into whether that is a well by well approval or some blanket authorizationlpool rule. West Sak injectors are, I believe, also completed packerless but do have a seal bore assembly and a finer top packer for the tieback string isolating the injection formation from the tubing-casing annulus. Below is a list of wells from a search of our well files that do not show a packer depth on the well completion report {10-407} or report of sundry operations {10- 404}, Please provide the MD and TVD of the uppermost liner top packer/seal bore assembly. Also, please remind those submitting the 404's and 407's of the uniqueness for these West Sak completions Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Fleckenstein, Robert J (DOA) Sent: Monday, March 03, 2008 1:06 PM To: Regg, James B (DOA) Subject: 10-404 converting a well to injector without packer MD Jim, The following wells have 10-404 submitted converting them from producers to injectors and have "none" or "no packer" in the packer MD data block: 2061100 WSAK 1J-102 2060670 WSAK 1J-156 3/12/2008 ~~ ~-pro~ Page 2 of 2 2060620 WSAK 1 J-170 2060470 WSAK 1 J-127 2060440 WSAK 1 J-184 2051230 KRU 1 C-20 BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 ~':E'Ie~~se nc>t~; ~~ew crn<til atlJt~ess bob,t`Iecken5teincci;alasla.gc~~- 3/12/2008 ;, ,~ \_ ~ ` ~ca~~~s~~'hillips Ata~sa, rec. -- 1 J-156 ~f -- ~' ,' ~ KRU 1J-156 HF'I: SSSV T e: SUUL`JL331 IUU NIPPLE vveu 1 e: Ori Com letion: INJ 7/28/2006 /\n ie a ia: An le TD: oe m 91 de 8281 Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE Reference Lo 28' RKB Ref Lo Date: Last U date: 12/28/2007 Last Ta TD: 8281 ftK6 Last Tan Date' Max Hnle Annle~ 94 den (a7 8027 ~ ~ ~ Casin 5trin -ALL STRINGS ~ s ?<] ~ ~ ~ ~ ` t _ ! I ~~~ 1 ~ 1 _-.-.: ~ 1 -- - i 1 ~ ~ ~ ...... _ ~ ~ - fI I1 ~ , { _I i._ ~... i_ -r ~ ~_ _~ t ~ ~__. Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.60 H-40 WELDED SURFACE 10.750 0 2768 2167 45.50 L-80 BTC INTERMEDIATE 7.625 0 6961 3625 29.70 L-80 BTCM D-SAND WINDOW 8.000 5697 5698 3422 0.00 B-SAND WINDOW 8.000 6072 6073 3490 0.00 A-S/'N[~! INFR 4.500 6160 8275 361 11 6n L-80 BTC Tubing String -TUBING Size Tip __ B~,tt~ m T'JD Wt Grad e Thread 1 `:~(I it ,.i~ ~1 i 12 ~~p L '0 IC~TP:1 Perforations Summary i..+cr..ol Tvn ~.,.,o c+~+~~~ G+ ~ coc ~ n~+o T....o r.,.r,.,.o..+ I 7043 - 7130 3631 - 3637 WS A2 87 32 7/9/2006 Slots Alternatin slotted/solid i e 7344 - 7387 3661 - 3664 WS A2 43 32 7/9/2006 Slots Alternatin slotted/solid i e 7431 - 7474 3665 - 3665 WS A2 43 32 719/2006 Slots Alternatin slotted/solid i e 7517 - 7561 3664 - 3663 WS A2 44 32 7/9/2006 Slots Alternatin slotted/solid i e 7602 - 7642 3663 - 3662 WS A2 40 32 7/9/2006 Slots Alternatin slotted/solid i e 7685 - 7728 3661 - 3660 WS A2 43 32 7/9/2006 Slots Alternatin slottedlsolid i e 7771 - 7814 3658 - 3655 WS A2 43 32 7/9/2006 Slots Alternatin slotted/solid i e 7857 - 7898 3652 - 3650 WS A2 41 32 7/9/2006 Slots Altematin slotted/solid i e 7941 - 7984 3648 - 3645 WS A2 43 32 7/9/2006 Slots Alternatin slotted/solid i e 8025 - 8068 3642 - 3640 WS A2 43 32 7/9/2006 Slots Alternatin slottedlsolid i e 8111 - 8155 3637 - 3635 WS A2 44 32 7/9/2006 Slots Altematin slotted/solid i e 8197 - 8241 3633 - 3632 WS A2 44 32 7/9/2006 Slots_ Alternating slotted/solid pipe Gas Lift Mandrels/Valves I St I MD i TVD Man Mfr I Man Type V Mfr V Type I V OD I Latch Port I TRO Date Run Cmnt If 1 3211 2396 CAMCO KBG-2-1R DMY 1.0 BK 0.000 0 9/26/2006 2 4985 3226 CAMCO KBG-2-1R DMY 1.0 7 BK 0.000 0 9/26/2006 -~ Other (plugs, equip., etc.) -COMPLETION i !tenth i T\/fl i Tvno i flccrrintinn i Ir1 i 22 22 HANGER VETCO GRAY TUBING HANGER, 4.909" TOP CONNECTION 4.500 497 496 NIP CAMCO'DB-6' NIPPLE w/3.875 NO GO PROFILE 3.875 5595 3401 SLEEVE-O BAKER CMD SLIDING SLEEVE OPEN 3.812 5646 3412 LOCATOR BAKER LOCATOR 3.875 5648 3412 SEAL BAKER 4.75 SBE SEAL ASSEMBLY 3.875 i tin rn i :tai / i tihl It i nn~ n_t ~rtc rr .flthar /nhinc omiin otr 5 _ ~_Cdtilrll JAIJ=R rIFTGII i v~,x i De th TVD T e Descti-lion ID 6161 3505 PACKER A-SAND'C2' ZXP LINER TOP PACKER 5.500 6178 3508 HANGER A-SAND FLEXLOCK LINER HANGER 5.510 6187 3510 SBE A-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 6207 3514 BUSHING A-SAND CROSSOVER BUSHING 3.930 8273 3631 SHOE A-SAND SILVER BULLET ECCENTRIC GUIDE SHOE 3.958 Other (plugs, equip., etc.) - D-SAND & B-SAND LEMs i f+onth i TVI~ ~ Tvno i ftccrnntinn i If) i 5640 3410 PACKER D D-SAND ZXP LINER TOP PACKER 4.970 5659 3414 SBR D D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 5679 3418 Bushin D D-SAND CROSSOVER BUSHING 3.950 5680 3418 PUP D D-SAND PUP 3.958 5684 3419 HANGER D D-SAND LEM ABOVE HOOK HANGER 3.980 5694 3421 HANGER D D-SAND LEM INSIDE HOOK HANGER 3.980 5694 3421 HANGER D D-SAND BAKER MODEL B-1 HOOK HANGER FOR LEM INSIDE CASING 4.500 5801 3443 PACKER B B-SAND ZXP LINER TOP PACKER 4.970 5820 3447 SBR B B-SAND 109-47 CASING SEAL BORE RECEPTACLE 4.750 5840 3451 Bushin B B-SAND CROSSOVER BUSHING 3.950 5841 3451 PUP B B-SAND PUP 3.958 6060 3488 HANGER B B-SAND LEM ABOVE HOOK HANGER 3.980 6070 3490 HANGER B B-SAND LEM INSIDE HOOK HANGER 3.980 i hn in i 34vn i IyHNlit Kfttl i H-tigNU HAKt-H MVUF! H-1 HCx)K FiWN/;tl-t FVH LCM (IN.I_"ItJt I:AtiIN1;1 i a !,nn i General Notes ~. I .~ FW: West Sak Injector 1J-15~otification of Defeated Low Pressure Pilot (LPP) Page 1 of 1 Mfaunder, Thomas E (©DA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent:. Saturday, October 27, 2007 8:46 AM To: Maunder, Thomas E (DOA}; Regg, James B (DOA) Cc: NSK West Sak Prod Engr, NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; Allsup- Drake, Sharon K; GPF1 DS Lead Techs; NSK Problem Well Supv Subject: FW: West Sak Injector 1J-156 : Notification of Defeated Low Pressure Pilot (LPP} Tom /Jim, ~-* ~c~ -oc~~ This email is to notify the AOGCC that the Low Pressure Pilot (LPP) on West Sak Injector 1J-156 (permit no.s 206-067, 206-068, 206-069) has been returned to normal function. Current injection rate is 1562 BWPD, injection pressure at the wellhead is 544 psi. Eric Hottar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 From: NSK West Sak Prod Engr Sent: Thursday, October 25, 2007 5:12 PM To: `tom_maunder@admin.state.ak.us'; 'jim_regg@admin.state.ak.us' Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Rodgers, lames T; CPFi Prod Supt; Allsup-Drake, Sharon K; CPFi DS Lead Techs; NSK Problem well Supv Subject: west Sak Injector 1)-156 : Notification of Defeated Low Pressure Pibt (LPP) Tom t Jim, This email is to notify the AOGGC that the (West Sak Injector) 1J-156 Low Pressure Pilot (LPP} is defeated as of 10/25/2007. This is in accordance with "Administrative Approval No. CO 4068.001" The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log." The 1J-156 was shut in 10/22!2007, and restarted today, 10/25/2007. It is anticipated that injection pressure will increase above 500 psi within a few days.. Current injection rate is 1575 BWPD, injection. pressure at the wellhead is 466 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 10/29/2007 West Sak Injector 1J-156 : Notification of Defeated Low Pressure Pilot~PP) Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Thursday, October 25, 2007 5:12 PM ~©~ ~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA} Cc: NSK West Sak Prod Engr, NSK Prod Engr Tech; Rodgers, James T; CPF1 Prod Supt; Allsup- Drake, Sharon K; CPF1 DS Lead Techs; NSK Problem Welt Supv Subject: West Sak Injector 1J-156 : Notification of Defeated Low Pressure Pilot {LPP) Tom /Jim, This email is to notify the AOGCC that the (West Sak Injector} 1J-156 Low Pressure Pilot (LPP) is defeated as of 10/25!2007. This is in accordance with "Administrative Approval No. CO 4066.001" The LPP and SSV {Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log." The 1 J-156 was shut in 10/22/2007, and restarted today, 10!25!2007. It is anticipated that injection pressure will increase above 500 psi within a few days. Current injection rate is 1575 BWPD, injection pressure at the wellhead is 466 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 10/26/2007 ~Cf~~~~tb~~ge~ ~pF~ °~ U 2oa~~ Schlumberger -DCS fir' , ,-~~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1~~~ ~_~-t~='~~~ 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 04/05107 1 2L-313 11628996 LDL 04/08/07 1 1D-137 11628997 INJECTION PROFILE 04/09107 1 2N-31.1A N/A USIT 04106/07 1 2N-337B 11638852 SCMT 04111107 1 1J-184 11638853 SBHP 04112/07 1 1H-10 11638844 GLS 03/20/07 1 2W-03 11649957 MEM LDLIPPROF 04/10/07 1 1E-112 11638856 INJECTION PROFILE 04114107 1 tJ-156 11638857 INJECTION PROFILE 04115107 1 1J-127 11638859 INJECTION PROFILE 04/17!07 1 1J-105 11628994 USIT 04106/07 1 1J-164 • 11638858 INJECTION PROFILE 04116/07 1 1J-164. 11638860 INJECTION PROFILE 04117/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~J c3 LPP Defeated On West Sak Injectors at DS1J Subject: LPP Defeated On West Sak Injectors at DSIJ From: NSK West Sak Prod Enbr <n1638@,conocophillips.coin> Date: Sun, 14 Tan 2007 10:08:32 -0900 1'0: "` l~on~ 11~1at~~xler:" 'tor~~maunder;r~;admin.state.ak.u~=~, "Jiro Ke~;~,:"" ~_ jimrr~~~~~~i-admin.statc.akus CC: Cl't=1 DS Laid Tc~hs < nl J -t~)~~i~conocophillihs.coi~1=~~, CPI 1 Nrod Sui~~ °--n l 1 >Z(r:cor~ocohhillihs.com> Tc~m !Jim, 1) The Low Pressure Pilot {LPP) for 1J-164 was defeated on 11810`7 in accordance with "Administrative Approval No. CO 4068.001."" The LPP and SSV have been tagged and recorded on the '"Facility Defeated Safety Device Log," ~1llellhead pressure dropped below 500 psi on 1/8107 after a foreign object became lodged in the restriction orifice {injection choke). The foreign object was removed on 1113f07 {yesterday) and injection rate was returned to normal. The wellhead pressure is now 468 psi {1634 bwpd) and is building back up to where it was before the 118107 event. l anticipate we wiCl need to keep the LPP defeated for ~1 week. The AO~CC wiil be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. 2} The Low Pressure Pilots for 1 J-127, 1 J-154, 1 J-156, and 1 J-170 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: 1J-127 1517 BV1lPD. 548 PSI 1J-154 1406 BWPD. 612 PSl -~ 1 J-156 3613 B1li1PD, 586 PSl ~Q~, °-(~(~,'"1 1J-170 2737 BWPD. 540 PSI Regards, Hai ai Hunt f Pete Nezaticky NSK Vilest Sak Production Engineer ConocoPhillips Alaska, lnc. Phone: {907} 659-7061 Fax: {907} 659-7749 Email: n1638{c~Gonocohillips.com 1 of 1 1/16/2007 11:07 AM 26-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-156 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) 8,281.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Si ned -c'~ ~ v ~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) - - ..~~~ STATE OF ALASKA • ~ p~ E ~~~~ ALASKA OILAND GAS CONSERVATION COMMISSION ,. ufCfxli~SBOft REPORT OF SUNDRY WELL OPERATIONS ' 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertordtions ^ Stimulate ^ Other ^/ Prod to WINJ '' Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ^ Exploratory ^ 206-067 / ' 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23311-00 ° 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-156 ' 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25660, 25663 Kuparuk River Field /West Sak Oil Pool . 11. Present Well Condition Summary: Total Depth measured 8281' feet true vertical 3631' feet Plugs (measured) Effective Depth measured 8273 feet Junk (measured) true vertical 3630 feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2659' 10-3/4" 2768' 2167' D-SAND WIND01 1' 7-5/8" 5698' 3422' _ B-SAND WIND01 1' 7-5/8" 6073' 3490' INTERMEDIATE 6852' 7-5/8° 6961' Perforation depth: Measured depth: Slotted liner 7043'-8241' true vertical depth: 3631'-3665' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5674' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 49T 12. Stimulation or cement squeeze summary: Intervals treated (measured) ' '~~~ ~ Q~. s .~ ,~~()b 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 2865 3536 72 1190 248 Subsequent to operation 2117 978 1 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ° Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG ^ GINJ ^ WINJ ~ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nva, if C.O. F~cempt: .306-321 contact Bob Christensen /.Bob Buchholz Printed Name Robert D. Christensen Title Production Engineering Technician Signature Phone 659-7535 Date ~., ,; ~ ; Form 10-404 Revised 04/2004 ~~(-~ ` Submit Original Only,`~~~/~ • 1 J-156 DESCRIPTION OF WORK. COMPLETED SUMMARY Date Event Summary 09/17/06 Well shut in for Producer to Injector conversion ' 10/01/06 Commenced Water Injection Service From: NSK Problem Well Supv <n1617@conocophilli~s.com% Date: Tue, 24 Oct 2006 16:56:10 -0800 `To: tom_maundcr(~r?admin.state.ak.us, jim_r~~~g(~r,~admin.state.ak.us, i~ob tlcckensteill<<iaclrnin.str~te.al~.us «MIT KRU 1D 10-22-06.x1s» «MIT KRU 1J 10-22-06.x1s» All, Enclosed are the state witnessed MITIA data for the two recent surface casing repairs 1 D-109, & 1 D-120 and the initial MITIA post conversion of 1J-127, 1J-1.56, and 1J-170. 3lXo-d~~ One thing to note regarding the 1J data is that all three wells are currently on a vacuum thus the tubing pressure is listed as zero. If you have any questions let me know Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com Content-Description: MIT KRU 1D 10-22-06.x1s ';'MIT KRU 1D 10-22-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT KRU 1J 10-22-06.x1s MIT KRU 1J 10-22-06.x1s Content-Type: application/vnd.ms-excel ': Content-Encoding: base64 1 of 1 10/30/2006 9:14 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1J 10/22/06 Greenwood /Noble Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-127 Type Inj. W ND 3,482' Tubing 0 0 0 0 Interval ( P.T.D. 2060470 Type test P Test psi 1500 Casing 1400 2180 2140 2140 P/F P Notes: Pre produced injectors, well on a vacuum OA 25 0 0 0 Well 1J-156 Type Inj. W ND 3,410' Tubing 0 0 0 0 Interval ( P.T.D. 2060670 Type test P Test psi 1500 Casing 750 2000 1950 1940 P/F P Notes: Pre produced injectors, well on a vacuum OA 0 0 0 0 Well 1J-170 Type Inj. W ND 3,391' Tubing 0 0 0 0 Interval I P.T.D. 2060620 Type test P Test psi 1500 Casing 1720 2200 2170 2160 P/F P Notes: Pre produced injectors, well on a vacuum OA 150 150 150 150 Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 1J 10-22-06.x1s RE: West Sak 1J-156 (PTD 206-067) conversion ofpreproduced inj... • • Subject: RE: West Sak 1J-156 (PTD 206-067) conversion ofpreproduced injector to water injection From: "Rodgers, James T" <James.T.Rodgersc~conocophillips.com> Date: Wed, 04 Oct ~O~J6 1 C~:O?:29 -0800 To: Thomas Maunder=~=tom maunder(u-~adt~~in.state.ak.uti° Thanks for the expedient response and your handling of this situation. James T. Rodgers GKA Production Engineering Supervisor james.t.rodgers@conocophillips.com Alaska North Slope NSK 69 Slope: 907-659-7226; pager 659-7000 x519 Town: 907-263-4353 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, October 04, 2006 2:30 PM To: Rodgers, James T Cc: jim_regg@admin.state.ak.us; NSK Well Integrity Proj; NSK West Sak Prod Engr Subject: Re: West Sak i]-156 (PTD 206-067) conversion of preproduced injector to water injection Mr. Rodgers, This message acknowledges receipt of your response concerning initiating injection into 1J-156 (206-067) and the laterals and that injection was halted the evening of October 3. The Commission is satisfied with the corrective actions CPAI has imposed and has decided not to pursue any enforcement action for this noncompliance. This event will be included in the 2nd quarter UIC report as required by our Compliance Assurance Agreement with EPA. If you have any questions, please contact me. Tom Maunder, PE AOGCC Rodgers, James T wrote, On 10/4/2006 10:53 AM: Tom, Thank you for pointing out that the sundries approving conversion of 1J-156 (PTD 206-067), -L1 (PTD 206-068), and L2 (PTD 206-069) from producer to injector were not approved at the time we started injection on 10/1/06. Although your note stated that the approval was granted yesterday, 10/3/06, CPAI had not received official notification so the well was immediately shut-in and freeze protected, pending receipt of sundry approval. I regret to inform you that the reason 1J-156 was put on injection early was due to human error. We've been working on four West Sak preproduced injector conversions as a package over the last month. Sundry applications were submitted for 1J-170, 1J-184, 1J-127, and 1J-156 within a two week time frame from 8/26/06 to 9/13/06. Wellwork and construction activities for these four conversions have been pursued in parallel. Sundry approvals had been received and communicated for 1 J-170, 1 J-184, and 1 J-127 around mid-September. Consequently, once 1 J-156 was ready to accept injection water, the assumption was made that the entire four well grouping had sundry approvals, when in fact, that was not the case. We did 1 of 4 10/4/2006 4:16 PM Re: [Fwd: West Sak 1J-156 (PTD 206-067) co~rsion of preproduc... • Subject: Re: [Fwd:'West Sak 1J-156 (PTD 206-U67} conversion of preproduced injector to water injection] From: John Norman <john_nonnan@adminatate.ak.us> Date: Wed, 04 Oct 2006 13:23.07 -0800 To: Cathy f~oersier~=cathy foerster«i':~~dmin.statc.akus-~ CC: jimrc'~!~iadmin.state.akus, toTn_it~~~under(~i~,admin.state.ak.us, dan seamount(u~admin.statc.ah.us I concur. Cathy Foerster wrote: I agree. -----Original Message----- From: James Regg To: Tom Maunder CC: Dan seamount; John K Norman; Cathy Foerster Sent: Wed Oct 04 11:58:13 2006 Subject: [Fwd: West Sak 1J-156 (PTD 206-067) conversion of preproduced injector to water injection] I suggest closing this out with a return note that simply states the Commission acknowledges CPAI's actions, is satisfied with the corrective actions imposed, and has decided not to pursue any enforcement action for this noncompliance. This will be included in the 2nd quarter UIC report as required by our Compliance Assurance Agreement with EPA. Jim Regg -------- Original Message -------- S ct: West Sak 1J-156 (PTD 206-067) conversion of preproduced injector to water i 'ectic Date: d, 04 Oct 2006 10:53:59 -0800 From: Ro , James T <James.T.Rod~ers(i~conocophillips.com> <tnailto:James. .. d<~ersrci).conoco hilli s.com> To: tam maunder a~ in.s_tate.ak:us CC: ~im re ~~vadmin,st ak.us, NSK Well Integrity Proj <N1878!a'; oco lailli s,com~ <mailto:N1878'i-Conoco chilli . ~ m> ,NSK West Sak Prod Engr < >38 z?conoco hilli s.com> Tom, Thank you for pointing out that the sundries a oving conve n of 1J-156 (PTD 206-067), -Ll (PTD 206-068), and L2 (PTD 206-069) from pro cer to injector were n proved at the time we started injection on 10/1/06. Although your note stated at the approval was granted ye day, 10/3/06, CPAI had not received official notification so the well was ' mediately shut-in and freeze protecte , nding receipt of sundry approval. I regret to inform you t the reason 1J-156 was put on injection early was due to humane .We've been working on four We Sak preproduced injector conversions as a package over the last month. ry applications wer submitted for 1J-170, 1J-184, 1J-127, and 1J-156 within a two week time frame fro /26 to 9/13/06. ellwork and construction activities for these four conversions have been pursued in parallel. Sundry a royals had been received and communicated for 1J-170, IJ-184, and 1J-127 around 1 of~ ~~~~~j~` ~~~''' J 10/4/2006 4:00 PM Re: West Sak 1J-156 (PTD 206-067) conversi~ f preproduced inje... • Subject: Re: West Sak 1J-156 (PTD 206-067) conversion of preproduced injector to waterinjection From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 04 Oct 2006 14:30:24 -0800 'I'o: "Ro~l~-recs. James T" <~~.lames.T.Rod~ers~cr;~conocophillips.conl~ CC: jimre~~~~,~r;admin.state.ak.us, N~K «'ell l~~te~~rit~~ Proj <=N1 ~+75'«!conoeophillips.com=~, NSK ~'~'csi Sak Prod F.n~r <cal(>~5r"~cconocophillips.coirl=~ BC'C:.fohn Norma~~ ~~ j~?h~~norm~m u?admin.state.ak.us=. Daniel h Sc~1m~~tint JR ~~=d~~nseanlount«z!adnlin.state.ak.us==~, Cath_y Foc;rstc< <cathy ioersterc~admin.state.ak.us=° Mr. Rodgers, This message acknowledges receipt of your response concerning initiating injection into 1J-156 (206-067) and the laterals and that injection was halted the evening of October 3. The Commission is satisfied with the corrective actions CPAI has imposed and has decided not to pursue any enforcement action for this noncompliance. This event will be included in the 2nd quarter UIC report as required by our Compliance Assurance Agreement with EPA. If you have any questions, please contact me. Tom Maunder, PE AOGCC Rodgers, James T wrote, On 10/4/2006 10:53 AM: Tom, Thank you for pointing out that the sundries approving conversion of 1 J-156 (PTD 206-067), -L1 (PTD 206-068), and L2 (PTD 206-069) from producer to injector were not approved at the time we started injection on 10/1/06. Although your note stated that the approval was granted yesterday, 10/3/06, CPAI had not received official notification so the well was immediately shut-in and freeze protected, pending receipt of sundry approval. regret to inform you that the reason 1J-156 was put on injection early was due to human error. We've been working on four West Sak preproduced injector conversions as a package over the last month. Sundry applications were submitted for 1 J-170, 1 J-184, 1 J-127, and 1 J-156 within a two week time frame from 8/26/06 to 9/13/06. Wellwork and construction activities for these four conversions have been pursued in parallel. Sundry approvals had been received and communicated for 1J-170, 1 J-184, and 1 J-127 around mid-September. Consequently, once 1 J-156 was ready to accept injection water, the assumption was made that the entire four well grouping had sundry approvals, when in fact, that was not the case. We did not follow our current process and confirm that sundry approval had been received specifically for 1J-156 prior to initiating injection. Following is our current process for following conversion applications. The responsibility for insuring AOGCC approvals have been granted lies within the Slope-based GKA Production Engineering team. 1. Our Production Engineering Technicians, Bob Christensen and Bob Buchholz, fill out and submit 10-403s (Application for Sundry Approval) to AOGCC based on anticipated timing of conversion execution by the Production Engineers. 2, The approved 10-403 is received from the AOGCC by the CPAI Engineering Aid (Sharon Allsup-Drake) in Anchorage, who then forwards it to the Production Engineering Technician. 3. The Production Engineering Technician places the 10-403 into the Slope master file and forwards a copy to the Production Engineer responsible for the well. 4. Prior to a well being brought online, a completed "Well Commissioning Check List" is required. 1 of 3 10/4/2006 4:00 PM Re: West Sak 1J-156 (PTD 206-067) conversion ofpreproduced inje... • This check list is reviewed by Project Engineers, Facility Engineers, Production Engineers, Operators, Instrument Technicians, and Production Superintendents and 15 individual tasks are signed off as complete. One of the line items the Production Engineer confirms as complete is 'Confirm that all well work, turnover forms, and sundry documents are complete and well is ready to be brought on line'. In this situation, the process failed when the Production Engineer signed off the Well Commissioning Check List without double checking that sundry approval for this specific well had been received. As mentioned above, the incorrect assumption was made that all four of these well conversion approvals had been received. I believe CPAI has a sound process that should normally be reliable. Following are actions being taken as a result of this incident to insure non-recurrence. 1. Our internal process is being reviewed with all Production Engineers as a refresher. 2. The Production Engineering Technician has always maintained a Sundry Tracking spreadsheet that tracks Sundry application dates, etc. An additional column was added to the Tracking sheet today entitled 'Sundry approval date/confirmation of receipt' so the entire approval chain is evidenced. A link to this spreadsheet will be distributed to all Production Engineers to make it much easier to view each Sundry application status at any time. The Tracking sheet has and will continue to be maintained as an evergreen document. 3. An Incident Review will be performed for this 1J-156 instance documenting process failure and appropriate actions to prevent a repeat occurrence. Please let me know if you need further explanations. James T. Rodgers GKA Production Engineering Supervisor fames.t.rodgers(a~conocophillips.com Alaska North Slope NSK 69 Slope: 907-659-7226; pager 659-7000 x519 Town: 907-263-4353 -----Original Message----- From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Tuesday, October 03, 2006 3:34 PM To: Rodgers, James T Subject: FW: West Sak Defeated LLP Notification *Correction* From: Thomas Maunder [mailto:tommaunder@admin.state.ak.us] Sent: Tuesday, October 03, 2006 2:22 PM To: NSK West Sak Prod Engr Cc: Jim Regg; NSK Well Integrity Proj Subject: Re: West Sak Defeated LLP Notification *Correction* Pete, Notifying us regarding the defeated pilots according to 460B.001 is appropriate. There is one problem with the notification however, the sundries approving conversion of 1J-156, -L1 and L2 from producer to injector were not approved until today. CPAI did not have authorization to begin injection into 1J-156 and the laterals. According to our compliance agreement with EPA, this is a "mis-injection" and is considered a significant noncompliance which could result in an enforcement action. I would appreciate if you would describe the process employed by CPAI in following conversion 2 of 3 10/4/2006.4:00 PM Re: West Sak IJ-156 (PTD 206-067) conversion ofpreproduced inje... • applications and approvals and why that process appears to have failed in this case. You should also include .what steps will be taken to insure that a similar event does not recur. I look forward. to your reply. Tom Maunder, PE AOGCC NSK West Sak Prod Engr wrote, On 10/3/2006 12:54 PM: Tom/Jim, ', I goofed on the defeated date the original email had 10/06/06 when it really was 10/01/06. I corrected the message below. ', Thanks, Pete From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Tuesday, October 03, 2006 12:50 PM To: Jim Regg; Tom Maunder Cc: NSK West Sak Prod Engr Subject: West Sak Defeated LLP Notification Tom /Jim, This email is to notify the AOGCC that 1J-127 and 1J-156 West Sak injectors, LPP (Low Pressure Pilot) have been defeated on 10/01/06 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". Following are the current well conditions: 1J-127: Converted from pre-production to injection 10/01/06. Injecting 1310 bwpd at 90 psi. 1J-156: Converted from pre-production to injection 10/01/06. Injecting 950 bwpd at 210 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 3 of 3 10/4/2006 4:00 PM Re: West Sak Defeated LLP Notification *Correction* • Subject: Re: West Sak Defeated LLP Notification *Correction* From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 03 Oct 2006 14:21:58 -0800 'Co: NSEt ~~~'cstSak Prod Fns;r<nl6>S(~i'conocot~hillips_com CC:.iim R<<~~~ ~ jitnrtc~~uiadmin.state.al:.us%. NSh ~~'ell In~e~~ril~~ Proj °~~N 1 ~7S«lconocophi llips.com BCC:.Iohn Norman <john norman~ci?admin.stat~.ak.u5>, Daniel "I~ Scailzonnt JR <dan sca_mount(ciadi~lin.siate.ak.us~> Pete, Notifying us regarding the defeated pilots according to 4606.001 is appropriate. There is one problem with the notification however, the sundries approving conversion of 1J-156, -L1 and L2 from producer to injector were not approved until today. CPAI did not have authorization to begin injection into 1J-156 and the laterals. According to our compliance agreement with EPA, this is a "mis-injection" and is considered a significant noncompliance which could result in an enforcement action. I would appreciate if you would describe the process employed by CPAI in following conversion applications and approvals and why that process appears to have failed in this case. You should also include what steps will be taken to insure that a similar event does not recur. I look forward to your reply. Tom Maunder, PE AOGCC NSK West Sak Prod Engr wrote, On 10/3/2006 12:54 PM: Tom/Jim, I goofed on the defeated date the original email had 10/06/06 when it really was 10/01/06. I corrected the message below. ', Thanks, Pete From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Tuesday, October 03, 2006 12:50 PM To: Jim Regg; Tom Maunder Cc: NSK West Sak Prod Engr Subject: West Sak Defeated LLP Notification Tom /Jim, ~ ao~-d6~ This email is to notify the AOGCC that 1 J-127 and 1 J-156 West Sak injectors, LPP (Low Pressure Pilot) have been defeated on 10/01/06 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". Following are the current well conditions: 1J-127: Converted from pre-production to injection 10/01/06. Injecting 1310 bwpd at 90 psi. 1J-156: Converted from pre-production to injection 10/01/06. Injecting 950 bwpd at 210 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. ~~~ ~, ~ ~~~ 1 of 2 11/2/2006 3:33 PM Re: West Sak Defeated LLP Notification *Correction* • '; Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 2 of 2 11!2/2006 3:33 PM • FRANK H. MURKOWSKI, GOVERNOR Re: Kuparuk River Field, West Sak Oil Pool, 1J-156 Sundry Number: 306-321 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 shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October, 2006 Encl. ~ut~ - vc~'~- Sincerely ConocoPhillips September 13, 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~` Ave. Ste. 100 Anchorage, AK 99501 Subject: Sundry Applications for Proposed Change of Well Class 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 ~~~C~~~~ SAP ~ ~ 2006 Alaska Oil & Gas Gons. Commis$q~ .. Anchorage ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on Kuparuk well 1J-156, 1J-156L1 and 1J-156L2. If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. ~~~~_ Robert D. Christensen Attachments: 10-403 Forms • ~6~~L __ ~~ ~~~~~~ STATE OF ALASKA ~ 1~~ t ALASKA OIL AND GAS CONSERVATION COMMISSION "-' ~I~D APPLICATION FOR SUNDRY APPROVAL SAP ~ g 2006 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ ~~Of1S, C~~j~~ Alter casing, ^ Repaicwell ^ Plug Perforations ^ Stimulate ^ Time Extensiofi ~~~ Chap Na proved ~c ram 9= P.' G 9 ^ PulLTubing , ^ Perforate New Pool ^ Re-enter Producer to Suspended Nhal ^ ' Injector 2. Operator Name:. 4. Current WeA Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-067 ' 3. Address: Stratigraphic ^ service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23311-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q 1J-156 9 Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661 & 25660, 25663 RKB 109' Kuparuk River Field /West Sak Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8281' 3631' 8273 3630 " Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 2659' 10-3/4'": 2768' 2.1.67 D-SAND WINDOW 1~ 7-5/8" " 5698' 3422 B-SAND WINDOW 1' 7-5/8" 6073' 3490 INTERMEDIATE 6852' 7-5/8" 6961' 3626 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted1iner7043'-8241' 3631'-3665' 4-~/2° L-80 5674' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 497' 13 Attachments` Description Summary of Proposal ~ 14, Well Class after proposed work: Detailed. Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 0 15: Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 1, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval:` Date: WAG ^ GINJ ^ W1NJ ~ WDSPL ^ Commission Representative 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob ChYistensen /Bob Buchholz Printed Name R Brt D. Ch ISt@nSe Title: Production Engineering: Technician Signature ~ ' Phone 659-7535 Date ~ 2 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness _3 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other. Subsequent Form Required: .. t q ;A ~ S ~~~ p;;T ~ 4 2~~6 1_i '-1~ ~ , ( ~ a t APPROVED BY ~ Approved by: OMMIS ONER THE COMMISSION /D-D~ Date: Form 10-403 Revised 06/2006 ~' `~ Submit in Duplicat ' 78,~ ~''~~r~ 1 J-156 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1 J-156. This well has been pre-producing for 27 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1J-156 will provide pressure support for the West Sak A sands. The 10-3/4" Surface casing (2769' and / 2167' tvd) was cemented with 498 sx Class G followed by 184 sx Class G. The 7-5/8" Intermediate casing (6961' and / 3626' tvd) was cemented with 405 sx Class G. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5640' and / 3410' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5801' and / 3443' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 6161' and / 3505' tvd. The top of West Sak D sand was found at 5683' and / 3419' tvd. ~r.. The top of West Sak B sand.~~s found at 6080' and / 3491' tvd. The top of West Sak A sand was found at 7024' and / 3630' tvd. r: . d ~anc~luc~~~11Ip~ A~~s~sa ~r~~. L' KRU 1 J-156 'f J-156 API: 500292331100 Well T : PROD An le TS: d SSSV T : NIPPLE Ori Com letion: 7/28/2006 An le TD: 91 d 8281 Annular Fluid: Last W/O: Rev Reason: GLV C/O Reference Lo : 28' RKB Ref Lo Date: Last U date: 8/9/2006 Last Ta TD: 8281 ftKB Last TaQ Dated Max Hole An le: Casin~ String _ ALL STRINGS _ Descri tion Size To 94 deg ~-8027 -_ _ ~ -- Bottom _-- -- ND -- - 1Nt rade hread CONDUCTOR 20.000 0 108 108 62.60 H-40 WELDED SURFACE 10.750 0 2768 2167 45.50 L-80 $TC INTERMEDIATE 7.625 0 6961 3625 29.70 L-80 BTCM D-SAND WINDOW 8.000 5697 5698 3422 0.00 B-SAND WINDOW 8.000 6072 6073 3490 0.00 A-SAND LINER Tubing String -TUBING 4.500 6160 __- -- 8275 - 3631 11.60 _ L-80 _ BTC __ _ Size To Bottom TVD Wt Grade Thread 4.500 0 5674 3417 12.60 L-80 IBTM ~'~~~" Perforations Summary - -- - _ _ - "~~' Interval ND Zone Status Ft SPF Date T e Comment 7043 - 7130 3631 - 3637 WS A2 87 32 6/9/2006 Slots Akernatin slotted/solid 7344 - 7387 3661 - 3664 WS A2 43 32 6/9/2006 Slots Akernating slotted/solid 7431 - 7474 3665 - 3665 WS A2 43 32 6/9!2006 Slots Akernating slotted/solid 7517 - 7561 3664 - 3663 WS A2 44 32 6/9/2006 Slots Akernatin slotted/solid 7602 - 7642 3663 - 3662 WS A2 40 32 6/9/2006 Slots Akernatin slotted/solid 7685 - 7728 3661 - 3660 WS A2 43 32 6/9/2006 Slots Akernatin slotted/solid 7771 - 7814 3658 - 3655 WS A2 43 32 6/9/2006 Slots Akernatin slotted/solid 7857 - 7898 3652 - 3650 WS A2 41 32 6/9/2006 Slots Akernatin slottedlsolid _ 7941 - 7984 3648 - 3645 WS AZ 43 32 6/9!2006 Slots Akernatinq slotted/solid 5595 3401 SLEEVE-O BAKER CMD SLIDING SLEEVE OPEN 3.812 5646 3412 LOCATOR BAKER LOCATOR 3.875 5648 3412 SEAL BAKER 4.75 SBE SEAL ASSEMBLY 3.875 5675 3417 SHOE MULE SHOE -- - - _- 3.958 -- Other {u s, a ui ., etc. - A-SAND LINER DETAIL Depth TVD Tvpe Description 7 _ ID ~I o iar - ocy i ~ _oooo - ooat_ I_ , vva roc ~ _ I 44 1 ~c ~ orarcvvo _~ Diva ~r~nc~nauny swucursona Pipe Gas`Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 3211 2396 CAMCO KBG-2-1 R GLV 1.0 BK 0.188 1456 8/8/2006 2 4985 3226 CAMCO KBG-2-1 R OV 1.0 BK 0.313 0 8/8/2006 Other lu s, equip., etc.--COMPLETION De h TVD T e Descri ion ID 22 22 HANGER VETCO GRAY TUBING HANGER, 4.909" TOP CONNECTION 4.500 497 496 NIP CAMCO'DB-6' NIPPLE w/3.875 NO GO PROFILE 3.875 ~ ~ 6187 3510 SBE 190-47 CASING SEAL BORE EXTENSION _ -p 6207 3514_ BUSHING CROSSOVER BUSHING k ` ~ 82 3737 13631 I SHOE SILVER BULLET ECCENTRIC GUIDE SHOE ~ == ' : ~ Other ( De h plugs, TVD equip., etc T e .) - D-SA'ND 8~ B-SAND LEMs Descri ion , _ 5640 3410 PACKER D ZXP LINER TOP PACKER ' 5659 3414 SBR D 190-47 CASING SEAL BORE RECEPTACLE 5679 3418 Bushin D CROSSOVER BUSHING ~ ~ "' - 5680 3418 PUP D ', ~ 5684 3419 HANGER D LEM ABOVE HOOK HANGER ~ w`' 5694 3421 HANGER D LEM INSIDE HOOK HANGER ', - 5694 3421 HANGER D BAKER MODEL B-1 HOOK HANGER FOR LEM INSIDE CASING ~ : 5801 3443 PACKER B ZXP LINER TOP PACKER 5820 3447 SBR B 109-47 CASING SEAL BORE RECEPTACLE >:?%s: i : 5840 3451 Bushin B CROSSOVER BUSHING i: ;s"'' 5841 3451 PUP B >:~ 6060 3488 HANGER B LEM ABOVE HOOK HANGER :. "~'''''' 6070 3490 HANGER B LEM INSIDE HOOK HANGER I " . `: 6070 3490 ,HANGER~B~ BAKER MODEL B-1 HOOK HANGER FOR LEM (INSIDE CASING).. _ -- _ _. :.General Notes r- --- -- - Date Note - -- - _ <<'!:> -_ [ '''.'''' ''' [ :! ~ 7/28/2006 MULTI-LATERAL WELL: 1J-156 (A-SANDS), 1J-156L1 (B-SANDS), 1J-156L2 (D-SANDS) TREE: VETCO GRAY/ HORZI 4-1/8" SM TREE CAP CONNECTION- 1/2" OTIS X4-1/8" 5M ID 4.970 4.750 3.950 3.958 3.980 3.980 4.500 4.970 4.750 3.950 3.958 3.980 3.980 4.500 -O~ ~ 1 ~C:iAN I CAL iI1TEGRITY RRPORT ~ - ~ ~ =-G ~- _' _ --_ r.~~_~.,... n LL DAT=- - ~1~~~ ~ ~/a~ -v c~ Casicg: ~~1~ OPER ~ FIELD C~~-.~.. ~~Zu ~Li NUMBER ~ ~ - 1S ~ °- \...tL - ~,.~ 1- TD . ~o~C~o ~ ~.. TVD ; ?BTD . ~ ~. Shoe :~_~ID 3~~ TVD ; DV : lu ~ ?.~ 1J~ T~~ -=:~e~ . ~yp. Shoe. '~ T`TD ; .OP . '_•~ _'iD ~o; .:_ . ~i tJ~<< Packer '~ T'J7i Set at S~~ ~ ole S~ie and ~C'r'~?~:Cc- L~ I~TTEGR?TY - ? Q.RT # I ~~~~~~~w~~~ p eTi; to L :~.~`~ ~~~ to O'Z 3 i~ ~ :~~~~ ~v.:, ,_5 ~5 ~S ._nr.ulus Press Test: _? ~ S ¢tin ~0 min Cor~ents '~• CHP N I C?1, INTE GRIT`S _ p Ag,-r # 2 ~ ~ L b .~ ~ h 4 ~~, Cement Voles :- r~.mt. Liner ~~ Cs°_ ~`~:~~.5~ ; DV ~(k Cr:t -JOI to cover hers ~~7cXS ~555b~~ ~~.~-~~C~ 5~~~~~r.~~~ __:eoretical TOC C 3a~ © XS ~~~C ~ ~`~~ ~oc~~~ ,~C ~~0 t!~- ~ ~ ~~~ (~ ~ r ~ CBL Evaluation, gone aoove perfs ~~ ~' - i~ (\ `l f ~ ~ ~ ',~\^.~\ yam, ~) F ~ Production Log: Type ~ ~,, ~, Evaluation ~~~^O~ CONCLUSIONS: - Part #1: ~ ~^ -i-, . ~- ~ Cement Bond Log (Yes or No) t~~j In AOGCC File ~~(,O OCc cement.bmp (BMA Image, 816x1056 pixels) mailbox:///F~/emaiUdefault/Mail/ancmail 1. state.ak.us/Inbox?number... Ceme nt Qetail Report 1 J-156 ~~' ~~0~ Intermediate Casing Cement Frin~ar i bT- ~ Jrt itgon,~ N.rE 4FE Y rt oats SG~d B. t~ End D.t pr('d CRILLPl FC_IPJ?.L ~ GEILLII ~~ 1 pt B81 ~ F ~g,20ob d ~a ~C06 ti iur; Cement ^etails oessri t. r r~r~, rrtl ra ~_ta~t oath ~-Pmarrt~~a er,~ D~~ '~r~~Pne~,~r~ r~~rr~u 1-dit' nterm ii~tr C~_:in~ ~~ern?nt nor n;_1 ~ ^, ~ni r' nZ~n 1 J-1 ~h Corcirnerd ~,II ~a~,'snt'ovell - Nn Frrr7i-~b-rn-~ _ :emetrt Stages utage # 1 Ed"R L~escri ption Ot~jec4i ~~? Top (ft Y;BI _ Bottom (ft Y;B~ Fuli Feturn ? Cmn[ Rtrn ... Top Plug? 6Yrn Fi ug? lrrterrr,a"ii_~tc C~u ~=rnt from ~_i (r~62' 3 R~,n_Ll -- r;,952D "'mss - 0.0 Yes Yes a~lo~~.o ~FSn~ t,ltskartjtbblimmJ t~tendjtbblhnmJ v[tavgttbbl hrnnt P(tinalt(psit P[bumpttpsij Recip? Stroke(ftj Rotated? Pipe RPM [rpm) 5 6 6 1,089.0 780.0 `§l~S ~ 2f)A0 No Oepthtagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Orill Out Diameter (in) O.D 6,875.0 Comment went weN - B~ on sUcs - Fbats taald. Cement FI s & Add Ives Fluid Edit Fluitl Type Flwd Descnption Eluneted Top (tth6) Est 69 rn (ft F,6) .~nuunt (sackst LI<ss volume F'urnped (bbl j Tail Cemerrt 3,650.0 6,962.0 405 G 163.0 5teld [ft'lsackj Mix H2O Ratio (gallsa... Free Water (5tj Density [Iblgalj Plastic Vlscosity[cp) Thickening Time (hrsj CmprStr 1 (psi] 2.25 7.42 12.50 173.1 5.00 AddRives Additive Type Concentration Conc Unit label Edit Low Temp Dis 8160 96BNVOC Additive Type Concentration Conc Unit Label Edit Antifoam D046 %BMlOC Additive Type Concentration Conc Unit label Edit Fluid Loss Corrtrol D167 %BNVOC Additive Type Concentration Conc Unit label Edit Acelerator (Calcium Chloride) D186 galJsx Page 1J9 Report Prirrted: 9J2tiJ2006 1 of 1 10/2/2006 3:34 PM RE: 1J-127 and 1J-156 • • Subject: RE: 1J-127and 1J-156 From: "Greener, Mike R." <Mike.R.Grcener@conocophillips.com> Date: Thu, 28 Sep 2006 14:.44;12 -0800 To: I~honuis ~launcfrr =-tom maunclcr(uadr~~in.statc.ak.us~~. Oka}~, I didn't realize that. Our netiv system slow places that data in the cementing ~•epol-t. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, September 28, 2006 2:34 PM To: Greener, Mike R. Subject: Re: 1J-127 and 1J-156 Mike, That is what I have attached to the completion report. But there is no information on reciprocating or full returns. These are some key descriptions that would be good to have. Thanks, Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 9/28/2006 2:25 PM: Here is the daily report for that day. Start End Dur Phase Op Code OpSub-Code Time Trbl Code Time Time P-N-T 0:00 0:15 0.251NTRM1 CASING SFTY P 0:15 2:15 2 INTRM1 CASING RNCS P 2:15 3:15 1 INTRM1 CEMENT CIRC P 3:15 3:45 0.5 INTRM1 CEMENT RURD P 3:45 5:45 2 INTRM1 CEMENT CIRC P Depth Depth Comm/Ope Start End 3,680.00 3,680.00 PJSM - Cre change - re hazards rur csg 3,680.00 6,962.00 Con't runnir 5/8" 29.7# BCTM csg 3689' to 69i TD Shoe jts + cut off #163) No problems running csg tight hole 6,962.00 6,962.00 Circu BU + Franks Too 2779 stks tc - PR 7 bpn 670 psi. Re csg 20' 6,962.00 6,962.00 R/D Franks - Blow do T R/U CMT h 6,962.00 6,962.00 Con't to Cin and conditic mud for CM 1 of 5 10/2/2006 3:36 PM RE: 1J-127 and 1J-156 • 5:45 7:45 2 INTRM1 CEMENT DISP 7:45 8:00 0.251NTRM1 CASING SFTY 8:00 9:00 1 INTRM1 CASING RURD 9:00 10:30 1.5 INTRM1 CASING NUND 10:3012:00 1.5 INTRM1 CASING NUND 12:00 12:15 0.25 INTRM1 CASING SFTY 12:15 12:45 0.5 INTRM1 CASING RURD LJ PR 7 bpm, 450 psi -Sty properties ~ 9.6 ppg, FV PV 9, YP 2' min gels 18 the After co MW 9.1+, F PV 10, YP ' min gels 6 P 6,962.00 6,962.00 Cement 7 5 Csg, Pump bbl CW 100 lines to 350 pump 65 bk pump 75 bk MudPush @ 12ppg, Drol bttm plug, F 163 bbls tai @ 12.5ppg, top plug, D: out w/ 2 bbl water. Rig displace wii MOBM, 31 stks, Bump w/ 500 psi c to 1350 psi. floats after "Held" -CIF 0730 hrs P 6,962.00 6,962.00 PJSM - Rey Slip setting procedures Review kno hazards P 6,962.00 6,962.00 P/U BOPs CMT head Clear tools rig floor T Wellhead/Tree 6,962.00 6,962.00 Vetco/Gray slips (plann Had trouble the first set slips would hold. Had tc and set sec set of slips. P 6,962.00 6,962.00 Cut Casing Pneumatic Cutter P 6,962.00 6,962.00 PJSM - inst packoff / Ni up BOP (pii points) P 6,962.00 6,962.00 Install pack Rig down c. tools and cl bales 2 of 5 10/2/2006 3:36 PM RE: 1J-127 and 1J-156 • 12:4513:45 1 INTRM1 CASING NUND 13:4515:001.251NTRM1 CASING OTHR 15:00 15:15 0.25 INTRM1 CASING SFTY 15:15 16:15 1 INTRM1 RIGMNT SVRG L J P 6,962.00 6,962.00 Nipple up B test pack of 3800 psi (1 i min). Instal wear ring. P 6,962.00 6,962.00 7-5/8" x 10- annulus infectivity to 9.0 ppg W E (11.8 ppg EMW). Pui 120 BBL frE water flush BPM IP 60( &FP730p: Stop pump stabilize @ psi & shut ii Freeze Proi Annulus w/ BBLs Diese 2.5 BPM IP psi & FP 70 P 6,962.00 6,962.00 PJSM -cut drill line (H~ Recognitior P 6,962.00 6,962.00 Cut & Slip c line 72', ins brakes, chE C-O-M,Luk Top Drive 8 Blocks -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, September 28, 2006 2:09 PM To: Greener, Mike R. Subject: Re: 1J-127 and 1)-156 Thanks Mike, I agree on this phenomenon being recent. Do you have some further details on the actual job? Like I said, what is in the summary with the completion report is pretty slim. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 9/28/2006 1:22 PM: The "channel" on the iJ-156 bond log could be the bead thing but I am still leaning to the "low side" effect of the well bore. The directional surveys show that we increased angle from 62 degrees at the beginning of the bond log to 80 degrees at the end. We reciprocated the pipe in 20' strokes up to when it was close to bumping the plug. I went back in time and looked at some earlier CBL's and I have noticed that the "bead channel" is not as pronounced in the earlier wells. I have Dowell's guy looking at the cement and will let you know what he 3 of 5 10/2/2006 3:36 PM RE: 1J-127 and 1J-156 • • finds out. -----Original Message----- From: Thomas Maunder [mailto:tom maunderC~admin.state.ak.us] Sent: Thursday, September 28, 2006 10:32 AM To: Greener, Mike R. Cc: Reilly, Patrick J Subject: Re: 1J-127 and 1J-156 Mike and Pat, The slope people have submitted sundries to convert 1J-156 -L1 and -L2 to injectors. On the bond log, the same comment regarding the beads segregating is made. Log doesn't look bad other than the "channel" that is shown. Have either of you had a chance to look at either log? Also, Mike, the description in the completion report is "short". In particular it does not say if the pipe was reciprocated. Can you help me here? I'd be interested in you all's thoughts regarding what shows to be a channel. Thanks, Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 9/13/2006 10:33 AM: I am also not familiar with this explanation. I believe that the interpretation is a stretch. I suspect that the channel is more a factor of the hole angle and it is likely that the "channel" is the low side of the casing string. But I cannot be sure as I have not seen the log. It is unlikely that the cement was fluid long enough to allow the bea to segregate themselves on one side of the hole. In conversation wit our cement guru, Mike Martin, the cement would have to be fluid longe than the time we allow before we displace the surface/intermediate annulus to make sure it is clear of cement. This well is Pat Reilly's well and he could probably give you a more complete description of what happened during the cementing job than I -----Original Message----- From: Thomas Maunder [ma_ilto:tom maunder=adm:i.n.state.a:k.us] Sent: Wednesday, September 13, 2006 9:57 AM To: Greener, Mike R. Subject: 1J-127 Mike, I was just looking at sundries to convert 1J-127, et al to injection. On the USIT, there is a comment that the "channel" in the presentatio is likely due to "density separation" of the "air filled ceramic bead 4 of 5 10/2/2006 3:36 PM RE: 1J-127 and 1J-156 • • used in the lite-Crete. The bond log looks pretty good, but there is the channel shown. The job log would not indicate there were any problems. Is this "density separation" something seen on other logs. I seem to remember some channels showing but not with this explanation. Thanks, Tom Maunder, PE AOGCC Content-Description: cement.bmp cement.bmp Content-Type: image/bmp Content-Encoding: base64 5 of 5 10/2/2006 3:36 PM 09/15106 • ~~ LJ Sebtu~berger ~ ~ tom. N0.3959 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth S~~ ~ ~ ZQ~~ ~„ • ~ ~/(~ ~ GAS. I~^fTMt'~a°.~;~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 ~~~ Anchorage, AK 99501 Cl i~ -V ~ ~- Field: Kuparuk Well Job # Log Description Date BL Color CD 2A-18 11213804 LDL 09/09/06 1 1A-20 11213802 PROD PROFILE W/DEFT 09/07/06 1 3A-17 11213803 PROD PROFILE W/DEFT 09/08/06 1 1J-156 11415621 PRODUCTION PROFILE 09/06/06 1 2A-13 11415619 PRODUCTION PROFILE 09/04/06 1 1L-28 11213805 PROD PROFILE W/DEFT 09/10/06 1 1L-10 1142164 INJECTION PROFILE 09/09/06 1 1J-102 11421625 USIT 09/11/06 1 2E-05 NIA INJECTION PROFILE 09/07/06 1 2E-05 11216326 SBHP 09/06/06 1 2U-03 11213007 INJECTION PROFILE 09/12/06 1 • Please sign and return one copy ofi this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1J-156 surface cement Subject: 1J-156 surface cement From: "Greener, Mike R." <MikeR.Greener ~conocophillips.com> Date: Thu, 07 Sep 2006 06:26:31 -0800 ~~~`~, _~ ~ ~~ To: 'T~on~ ~laund~r ~~[oili maunderr~~l;a~lmin.statc.ah.us~ ['C: "Al1suE~-Drake, Sharon K" °-Sharon.IL.%~llsup-Drakeu conocophilliE~S.com The surface cement job on the 1J-156 had 121 bbls of cement returned to surface. I believe l knave why this was missed on the report. We have a new reporting syTstem called Wellview anal the amount of ce~r~ent retLrn~ed to surface is recorded in a diffez•ent place than usual. I have attached a copy of the cement report foc you. l-lope this clears up the problem. «1J-156 Surface Cement.pdf» Mike trreener «Greener, Mike R..vcf» Content-Description: 1 J-156 Surface Cement.pdf 1J-156 Surface Cement.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 9/7/2006 7:24 AM i Primary Job Type DRILLING ORIGINAL Cement Details Description Surface Casino Cement Cement Detail Report 1 J-156 ~, '--~ ~, j DRILLING Surtace Casing Cem~ E / RFE Staff rt Date Sup d Dat E dne Date 10139812 i 6!29/2006 i 6/29/2006 ~ 7/28/2006 Cementing Siart Date Cementing End Date i~eiibore (Jame 712!2006 01:45 , 712/2006 05:15 1J-156 Cement Stages StacJe # 1 Description Ob)ective iop (ftKB) Bottom (ttK6) FuYi Return % ~ilnnt Rtrn ... Top Plug? ~ Btm Plug`t Surtace csg CMT Surface Pipe from 28.0 2,769.0 Yes /i 121.0 r Yes ~ Yes Top tp bttm. ( ~ Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbllmin} P (f;nal) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Plpe RPM (rpm) 6 4 5 ~ 622.0 1,098.0 Yes 15.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 2,684.0 Comment We were able to recip csg thru 133 bbis of displacement out of 234 bbls and had 10.7 ppg CMT to surface. After pump 56 more bbls (189 bbls into displacement) the pipe begain to be sticky. After the string would not go back down on the landing ring the hanger was set at 6.5' above the landing ring to clear the pup collar for the emergency slips. Cement Fluids & Additives Fluid Fluitl Type Fluid Description Estimated Top (ftKB) Est Bim (ftKB) Amount(sacks) Class Volume Pumped (bbl) Lead Cement 10.7 -28.0 1,907.0 498 G 410.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (I) Density (Ib/gal) Plastic Viscosity (cp} Thickening Time (hrs) CmprStr 1 (psi) 4.63 21.75 10.70 11.9 6.00 Additives Additive ~ Type Concentration Conc Unit label Sa{t D044 9.0 %BWOW Additive _ Type Concentration Conc Unit label Antifoam D046 0.6 %BWOC Additive J Type Concentration Conc Unit label Thixotrop ~D053 30.0 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.5 %BWOC _ Additive ` Type Concentration Conc Unit label Extender D079 1.5 %BWOC Additive Type Concentration Conc Unit label Extender d124( .78) 50.0 %BWOC Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) S001 1.5 %BWOC Fluid Fluid Type Tail Cement Fluid Description 12.0 Estmated iop (ftKB) 1,907.0 Est Btm (ftKB) 2,769.0 Amount (sacks) 184 Glass Volume Pumped (bbl) G 80.6 Yield (fPJsack) Mix H2O Ratio (gat/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 2.47 8.18 ~ 120.00 4.00 Additives , _ Additive __ __ Type Concentration Conc Unit label Low Temp Dis ' 6160 0.2 °loBWOC Additive Type Concentration Conc Unit label Antifoam 46 0.6 %BWOC __ _ Additive ~ Type _ Concentration Conc Unit label Fluid Loss Control D167 _ Additive Type _ _ _ __ Concentration Conc Unit label Accelerator D186 0.04 i oal/sx Page 1!8 Report Printed: 9/7/2006 • ConocoPhillips August 22, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~~ V EV SEP 6 2006 Alaska Oil & Gas Cons. Commission Anchorage Subject: Well Completion Reports for 1J-156, 1J-156L1 and 1J-156L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent dri{ling operations on the West Sak wells 1 J-156, 1 J-156L1, 1 J-156L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~ _.. R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad R. ~~', STATE OF ALASKA ~ S E [~ 4 ' 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION S;~IOp WELL COMPLETION OR RECOMPLETION REPd~ ~ " 1a. Well Status: Oil Q Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., .~~ ~.i, or,4band.: July , 2006 12. Permit to Drill Number: , 206-067 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 29, 2006 13. API Number: 50-029-23311-00 4a. Location of Well (Governmental Section): Surface: 2094' FSL, 2559' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: July 9, 2006 14. Well Name and Number: 1J-156 ' At Top Productive Horizon: 758' FNL, 308' FEL, Sec. 3, T10N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. FieldlPool(s): Kuparuk River Field Total Depth: 2012' FNL, 314' FEL, Sec. 3, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 8273' MD / 3630' TVD West Sak Oil Po01 ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558649 ' y- 5945905 ' Zone- 4 10. Total Depth (MD + ND): 8281' MD / 3631' TVD ' 16. Property Designation: ADL 25661 a~ 25660, 25663 TPI: x- 555646 y- 5943030 Zone- 4 Total Depth: x- 555651 ' - 5941777 • Zone- 4 11. Depth where SSSV set: nipple @ 497' 17. Land Use Permit: ALK 472 18. Directional Survey: Yes ~ No ^ 19. Water Depth, if Offshore: N!A feet MSL 20. Thickness of Permafrost: 4077' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 94# K-55 28' 108' 28' 108' 42" 163 sx Class G 10.75" 45.5# L-80 28' 2769' 28' 2167' 13.5" 498 sx Class G, 184 sx Class G 7-5/8" 29.7# L-80 28' 6961' 28' 3626' 9-7/8" 405 sx Class G 4.5" 11.6# L-80 6160' 8275' 3505' 3631' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 5675' slotted liner from 7043'-8240' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST ' Date First Production August 17, 2006 Method of Operation (Flowing, gas lift, etc.) Pre-produced injector- shares production with 1J-156L1 and 1J-156L2 Date of Test 8/20/2006 Hours Tested 15 hours Production for Test Period --> OIL-BBL 1681 GAS-MCF 3073 WATER-BBL 33 CHOKE SIZE 85 Bean GAS-OIL RATIO 1921 Flow Tubing press. 578 psi Casing Pressure 1320 Calculated 24-Hour Rate -> OIL-BBL 2565 GAS-MCF 4928 WATER-BBL 53 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". co~n~LErlard NONE VfflIFfED Form 10-407 Revised 12!2003 CONTINUED Ot~l E~~ ~ ~ e•~ /f~` 5 Q~'~ ~~i ~~I~~ ~F~ CEP q ~ 2006 H `/~ i~~- ~t~la~ ~ i 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-156 Top West Sak A2 7024' 3630' ' Base West Sak A2 7141' 3638' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed N Rand Thomas Title: Greater Kuoaruk Area Drilling Team Leader ~ / ~ ~ Si nature one - Date ~ ~ L' g Z~.s G-~ s ~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low !ow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~onoctiPhiiiips ~ Time Log Summary We1h7~w bNeb ReAarCing Time Logs `'Date From _ To Dur S. De th E De th Phase Code Subcode T COM 06/29/2006 00:00 08:00 8.00 0 0 MIRU MOVE DMOB P Move rig off of 1J-170 and spot up rig and all modules over 1J-156. No problems and no incidents. Rig Acce ted 08:00 hrs. 08:00 10:00 2.00 0 0 MIRU MOVE RURD P N/U Diverter, Load pipe shed w/ drill pipe and strap same, weld toe board in derrick. Rig on Hi-Line power @ 09:00 hrs. 10:00 12:00 2.00 0 0 MIRU MOVE RURD P C/O saver sub, grabbers and bell guide to 4-1 /2" I F 12:00 13:15 1.25 0 0 MIRU MOVE RURD P Space out grabbers & safety wire top drive, clear rig floor, R/U floor and pipe shed to P/U 5" DP. 13:15 14:15 1.00 0 0 MIRU WELCT BOPE P Perform Diverter test w1 State Man, Co. Rep, & Motorman. Diverter test witnessed by AOGCC rep Lou Grimaldi. Bag Close @ 47 sec. Knife valve close @ 7 sec. Accumulator psi before shut in = 3000psi, after = 1900 psi. 200 psi recovery = 44 sec. Overall recovery = 3min 8 sec. 5 bti avg = 2300 psi. Diverter Length 148' fom center of well. Gas alarms calibrated and tested. 14:15 17:30 3.25 0 0 MIRU DRILL PULD P P/U 30 stands 5" DP, 6 stands 5" HWDP w/ Jars, 1 stand 8" non-mag, some-o s mix s ud mud 17:30 18:30 1.00 0 0 MIRU DRILL PULD P M/U and stand back 1 stand Non-mag DC 18:30 21:30 3.00 0 0 MIRU DRILL PULD P P/U motor, re-orient sleeve on motor, M/U stabilizer & float sub 21:30 22:00 0.50 0 0 MIRU DRILL PULD P M/U bit, flood conductor and check for leaks. 22:00 22:15 0.25 0 0 MIRU DRILL PULD P Continue M/U BHA 22:15 22:30 .0.25 0 108 SURFA DRILL DRLG P Wash and drill ice from 90' to 108' 22:30 00:00 1.50 108 150 SURFA DRILL DRLG P Spud Well -Drilling from 108' to 150'. ART = 1.2 hrs 06/30/2006 00:00 00:30 0.50 150 224 SURFA DRILL DDRL P Cont. Drilling from 150' to 224'. HART _ .5 00:30 01:00 0.50 224 224 SURFA DRILL TRIP P POOH to C/O BHA 01:00 01:15 0.25 224 224 SURFA DRILL PULD P M/U BHA, MWD, UBHO 01:15 01:30 0.25 224 224 SURFA DRILL PULD P Orient MWD to Motor 01:30 02:00 0.50 224 224 SURFA DRILL PULD P R/U Gyro 02:00 02:30 0.50 224 224 SURFA DRILL TRIP P RIH to 133' and Tag hard fill, UD 1 jt NMFDC & P/U stand of HWDP ~~~~.v ~ A e.__._e __em _ ~e ~ .~~ ~ ~.~e. ~~... P~g~ 1 t~~ - - ~ ~~ -~,.~._.~ -._.t Time Logs Date From To Dur e th E. De th Phase Code Subcode OM 06/30/2006 02:30 03:00 0.50 224 224 SURFA DRILL REAM. P Wash & Ream from 133' to 224' 03:00 03:15 0.25 224 224 SURFA DRILL TRIP P PIU 1 jt NMFDC & R1H to 224' 03:15 12:00 8.75 224 718 SURFA DRILL DDRL P Drilling from 224' to 718' MD (700' TVD). AST = 3.12, ART = 2.69, ADT = 5.81. Gyro @ 253' 20 min. Gyro @ 346' 20 min. Gyro @ 440' 20 min. Gyro @ 622' 20 min. PU = 74k, SO = 70k, Rot Wt = 70k, TQ on btm = 1-2k, TQ off btm = 1-2k, Jar Hrs = 63.17 12:00 00:00 12.00 718 1,870 SURFA DRILL DDRL P Drilling from 718' MD (700' TVD) to 1870' MD (1693' ND), 130 spm, 530 gpm, 1475 psi on btm, 1250 psi off btm, 20-30k WOB, 85 rpm, PU = 92k, SO = 80k, TQ on btm = 5k, TQ off btm = 1 k, ADT = 8.45 hrs, ART = 6.22 hrs, AST = 5.01 hrs, Mssi3c G~ = 8T units, Jar hrs = 71.62, Bit hrs = 14.26 07/01/2006 00:00 00:15 0.25 1,870 1,870 SURFA DRILL SFTY P PJSM -Hazards of drilling and connections -Getting tools in and out from beaver slide 00:15 08:45 8.50 1,870 2,780 SURFA DRILL DDRL P Con't Drlg f/ 1870' to 2780' MD / 2173' TVD - TD surface csg point - Up wt 110k, Dn wt 75k, Rot wt 87k, Torq on and off bttm 7k. ADT 6.01 (2.81 Rot, 3.20 slide Jars = TT 77.63 08:45 09:00 0.25 2,780 2,780 SURFA DRILL CIRC P Circu 10 min to clear assy -Flow ck well -Static 09:00 12:00 3.00 2,780 1,095 SURFA DRILL TRIP P BROOH f/ 2780' MD to 1095' MD - PR 600 gpm, RPMs 85" '""' Hed hydrates gas 19$4 units @ 207tY #~1D/ 1816' N[~ ~rttt 211 ~' ' ~ 2358' MDI 1~1' TVD- 12:00 15:15 3.25 1,095 0 SURFA DRILL TRIP P Con't BROOH 1095' MD ghost reamer ( Top HWDP) - LD Ghost reamer - POOH to monels. - LD BHA #1 15:15 15:45 0.50 0 0 SURFA DRILL PULD P Clear all tools from rig floor -Clean rota area 15:45 17:00 1.25 0 0 SURFA DRILL RURD P RU to run 10 3/4" Csg. 17:00 17:30 0.50 0 0 SURFA DRILL SFTY P PJSM -Discuss know hazards - Review runnin detail 17:30 22:45 5.25 0 2,776 SURFA CASIN( RNCS P Run Surface Csg -Run 67 jts + 2 pup joints 10 3/4" 45.5# L80 BTC csg - Shoe @ 2776' MD/2171' TVD *"*NOTE"*"' Had 1 small tight spot around the base of perms-frost (Jt #44 1848' MD) Took a little wt 25k - No roblem 22:45 00:00 1.25 2,776 2,776 SURFA CASIN( CIRC P Circu and Condition w/ Franks Tool - PR 7 bpm, PP 550psi , Up wt 150k, Dn wt 78k 07/02/2006 00:00 00:15 0.25 2,776 2,776 SURFA CASIN( SFTY P PJSM on rigging down Franks tool & R/U cement head t---- ,.Time Logs ~-~ Date From To Dur ~e t~h E. De th Phase Code Subcode OM 07/02/2006 00:15 00:30 0.25 2,776 2,776 SURFA CASIN( RURD P Rig down Franks tool & rig up cement head 00:30 02:00 1.50 2,776 2,776 SURFA CEMEf~ CIRC P Cont. circ & cond mud for cement 70 s m, 350 si 02:00 02:15 0.25 2,776 2,776 SURFA CEMEI~ SFTY P PJSM on cementing 02:15 05:30 3.25 2,776 2,776 SURFA CEME~ DISP P Cement surface casing, 5 bbls, H2O test lines 3000 psi, 50 bbls. CW100, 50 bbls, Mud push, drop bottom plug, pump lead 410 bbls, 10.7 ppg, pump tail 80 bbls, 12 ppg, drop top plug, 20 bbls wash tub & lines, dosplace with ri 2350 strokes CIP 05:15 05:30 07:30 2.00 2,776 2,776 SURFA CASIN( RURD P Flush riser, take turn buckles off, take off diverter pipe, P/U on diverter stack to set emer enc sli s 07:30 08:30 1.00 2,776 2,776 SURFA CASIN( RURD P Set Slips (w/ 65k overpull) 08:30 09:00 0.50 2,776 2,776 SURFA CASIN( OTHR P Drain & cut off casing 09:00 12:00 3.00 2,776 2,776 SURFA CASIN( RURD P R/D diverter stack & clean cement out of same, ull out of cellar 12:00 13:00 1.00 2,776 2,776 SURFA CASIN( NUND P UD long bails, R/U 4" handling tools, sime-ops: weld on starting head flange, repair drag chain in pits, clean R/W, P/U mousehole 13:00 14:45 1.75 2,776 2,776 SURFA CASIN( RURD P Recharge accum bottles on top drive, UD 7 stds 5" DP in mousehole, some-ops -pull diverter sys out under roduction lines. Retrieve 3 test 'oints. 14:45 15:15 0.50 2,776 2,776 SURFA CASIN( OTHR P R/U 4" handling tools, PJSM & hazzard assessment on C/O saver sub. 15:15 16:45 1.50 2,776 2,776 SURFA CASIN( RURD P C/O 4-1/2" IF saver suv to 4" XT-39, sime-ops P/U starting head, collect tools, re are fro ni lin u in cellar 16:45 22:00 5.25 2,776 2,776 SURFA CASIN( OTHR P P/U 144 jts 4" XT-39 DP in mousehole, rack back in derrick 22:00 00:00 2.00 2,776 2,776 SURFA CASIN( RURD P M/U 4" & 5" floor valves, M/U 1 std 6-3/4" non mag & rack back in derrick, UD mousehole, grease choke manifold, get test plug & wear ring uller from Vetco Gre 07/03/2006 00:00 00:15 0.25 0 0 SURFA CASIN( NUND P PJSM -discuss and review NU Well Head and BOPs 00:15 00:30 0.25 0 0 SURFA CASIN( DHEQ P Test weld on adaptor well head. 1900 si 10 min "OK" 00:30 01:00 0.50 0 0 SURFA WELCT NUND P NU Well Head on adapter 01:00 03:00 2.00 0 0 SURFA WELCT NUND P NU BOPs 03:00 09:00 6.00 0 0 SURFA WELCT BOPE P Test BOPS and Choke manifold - 250 psi low and 3000 psi high - No failures - All test charted and held 5 min. AOGCC rep John H. Crisp waived witness test. ~~ ag ~ cif ~2 ~~ ~ ~ _ ~.. ~ Time Logs _ Date_ From To Dur th E. Depth Phase Code Subcode T_ OM 07/03/2006 09:00 09:15 0.25 0 0 SURFA DRILL SFTY P PJSM -Discuss and review PU BHA 09:15 10:15 1.00 0 80 SURFA DRILL PULD P PU BHA #2 - Motor, MU bit, Flt sub, Stab, HOC, MWD, TM 10:15 10:45 0.50 80 80 SURFA DRILL SRVY P Up Load MWD 10:45 11:30 0.75 80 452 SURFA DRILL PULD P Con't PU BHA #2 -TIH w/ NMDCs, 8 'ts HWDP + Jars, XO 11:30 12:00 0.50 452 452 SURFA DRILL SRVY P Pulse Test MWD "OK" 12:00 12:15 0.25 452 460 SURFA DRILL PULD P PU Ghost reamer 12:15 13:00 0.75 460 2,597 SURFA DRILL TRIP P TIH to 2597' -Circu air from system 13:00 14:00 1.00 2,597 2,597 SURFA CASIN( DHEQ P RU and Test csg to 3000 psi on chart for 30 min -Good test - No bleedoff 14:00 15:30 1.50 2,780 2,805 SURFA CEME~ DRLG P Drlg out Flt collar, shoe track, Flt shoe 2769' MD w! 9 7!8" bit, FR 450 gpm, PP 1100 psi, RPMs 60-65, Torq 5-8k, lus 25' of new hole to 2805' MD 15:30 17:00 1.50 2,805 2,805 SURFA DRILL CIRC P Circu re-conditioned mud around - Circu until mud is uniform in and out. 17:00 17:30 0.50 2,769 2,769 SURFA DRILL LOT P Pull to shoe - RU and Preform LOT - MW 9.0 ppg, 2169' TVD, 382 psi at surface = 12.4 EMW 17:30 18:00 0.50 2,805 2,867 INTRM1 DRILL DDRL P Drlg 9 7/8 "hole w/Motor f/ 2805' MD to 2867' MD ! 2214' TVD - PR 550 m, PP 1250 si, WOB 8-10k, 18:00 19:00 1.00 2,867 2,867 INTRM1 DRILL SRVY T Trouble Shoot MWD - No Signal 19:00 19:30 0.50 2,867 2,867 INTRM1 DRILL CIRC T Circu BU -Max gas units 616 units 19:30 19:45 0.25 2,867 2,867 INTRMI DRILL OWFF T Obsevre Well -Static 19:45 21:45 2.00 2,867 150 INTRMI DRILL TRIP T POOH on elevators f/ 2867' 21:45 22:15 0.50 150 110 INTRMI DRILL SRVY T Down Load MWD 22:15 22:45 0.50 110 60 INTRM1 DRILL PULD T LD MWD, TM collar & HOC 22:45 23:15 0.50 60 150 INTRM1 DRILL PULD T PU New MWD tool, TM collar & HOC 23:15 00:00 0.75 150 150 INTRM1 DRILL SRVY T Up Load MWD 07/04/2006 00:00 00:15 0.25 150. 150 INTRM1 DRILL SFTY T PJSM on TIH 00:15 00:30 0.25 150 452 INTRMI DRILL DHEQ T TIH T/ 452' MD & Shallow test MWD OK 00:30 01:30 1.00 452 2,768 INTRM1 DRILL TRIP T TIH T/ 2768' MD 01:30 02:00 0.50 2,768 2,768 INTRM1 DRILL CIRC T Circ Bottoms up, Gas cut 504 units, circ 500 al/min & 1100 si 02:00 02:15 0.25 2,768 2,865 INTRM1 DRILL TRIP T TIH F/ 2768' MDT/ 2865' MD, Survey on bottom 02:15 03:45 1.50 2,867 3,055 INTRM1 DRILL DDRL P Drilling F/ 2867' MD to/ 3055' MD m _. _.._._ ~ ~'~ge ~ oaf ~~ ~. ..~., ~. Time Logs Date From To Dur e th E_De~th Phase Code Subcode T OM 07/04/2006 03:45 04:15 0.50 3,055 3,055 INTRM1 DRILL SRVY T MWD Detection problems 04:15 12:00 7.75 3,055 3,940 INTRM1 DRILL DDRL P Drilling F/ 3055' MDT/ 3940' MD (2759' TVD), ADT = 5.52, AST = 2.68, ART = 2.84, PU = 112k, SO = 70k, ROT = 85k, TQ = 7k On abtm & 6k off btm, ECD = 9.65, Max Gas = 53 units dlg, 504 units on TIH, Jar hrs = 80.24, PR @ 3800' MD, 2691' TVD, MW = 9.0 ppg, MP #1 @ 30 spm = 250 psi, @ 40 spm = 320 psi, MP#2 @ 30 spm = 250 si, 40 s m = 320 si 12:00 00:00 12.00 3,940 5,088 INTRM1 DRILL DDRL P Held PJSM & Hazard assesment on drilling ahead & making connections, Drilling F / 3940' MD (2759' TVD) to 5088' MD (3266' TVD), 550 gpm, 1700 psi, 131 spm, 90 RPM, 10-20k WOB, ADT = 13.16, ART = 3.75, AST = 3.89, PU = 110k, SO = 78k, ROT = 92k, TQ = 5k on btm & 4.5k off btm, ECD = 9.91, Max GAs = 86 units, Jar hrs = 87.88, SPRs @ 5018' MD, 3238' TVD, MW=9.0, MP#1 @30 spm=320 psi, @ 40 spm = 410 psi, MP #2 @ 30 spm = 320 psi, @ 40 spm = 400 si 07/05/2006 00:00 00:15 0.25 5,088 5,088 INTRM1 DRILL SFTY P PJSM on drilling ahead & making connections 00:15 12:00 11.75 5,088 5,850 INTRM1 DRILL DDRL P Drlg from 5088' MD to 5850' MD (3452' TVD). ADT = 8.61, AST = 2.09, ART = 6.52, PU = 110k, SO = 75k, ROT = 90k, TW = 6k on btm & 5-8k off btm, ECD = 9.65, Max Gas = 67 units, Jar hrs = 96.49. SPR @ 5802' MD (3443' TVD) w/ MW = 9.1 ppg: #1 MP @ 30 spm = 320 psi, @ 40 spm = 410 psi; #2 MP @ 30 spm = 320 psi, @ 40 s m = 410 si 12:00 12:15 0.25 5,850 5,850 INTRM1 DRILL SFTY P PJSM on drilling ahead, scrubbing windwails, & hazard assesment 12:15 00:00 11.75 5,850 6,699 INTRM1 DRILL DDRL P Dlg from 5850' MD (3452' TVD) to 6699' MD (3588' TVD). ADT = 7.24, ART = 4.94, AST = 2.3, PU = 115k, SO = 72k, ROT = 90k, TQ = 5-6k on btm & 6k off btm, ECD = 10.09, Max Gas = 198 units, Jar hrs = 103.73. SPRs @ 6699' MD (3588' TVD) w! MW = 9.2+: MP #1 @ 30 spm = 370 psi & @ 40 spm = 450 psi; MP #2 @ 30 s m = 370 si & 40 s m = 450 si 07/06/2006 00:00 00:15 0.25 6,699 6,699 INTRMI DRILL CIRC P PJSM -Discuss drilling hazards & BROOH ~~®~ _._®,.... ~ ,..~ ~'~g~ ~ 22~ Time Logs Date Fr m To Dur th E. de th Pha e Code Subcode 7 QOM 07/06/2006 00:15 02:45 2.50 6,699 6,968 INTRM1 DRILL DDRL P Directional Drlg w/ Motor 6699' to 6968' MD ! 3625' TVD. Up wt 120k, Dn wt 70k, Rot wt 85k On bttm torq 6-7k, PR 550 gpm, PP 2000 psi, Total ADT 2.31 hrs, (ART 1.44, AST .87), Total hrs on jars = 105.5. ""*Note"" Jars came out of hole half cocked. These will be sent in to weartherford to be ins ected. 02:45 03:45 1.00 6,968 6,968 INTRM1 DRILL CIRC P Pump &Circu Wt! HiVis ,Noted 10% increase in cutting when back to surface, PR 550 gpm, PP 2000 psi, RPMs 90. Hole appears to be in good sha a and clear of cuttin beds. 03:45 09:15 5.50 6,968 2,769 INTRM1 DRILL TRIP P Flow Ck well- Static - BROOH f/ 6968' to 2769'. PR 500 gpm, RPMs 90. All pulled well - No signs of pack off or cuttin roblems. 09:15 10:30 1.25 2,769 2,769 INTRM1 DRILL PULD P Std back last 2 stds 4" DP - UD all 5" DP 36 'ts 2769' to 1569' 10:30 12:00 1.50 2,769 2,769 INTRM1 DRILL CIRC P Circu & Pump Sweep at shoe until clean, PR 550 gpm, PP1300 psi, RPMs 50 12:00 13:15 1.25 2,769 311 INTRM1 DRILL SFTY P PJSM -Discuss hazards LD DP POOH & LD BHA 13:15 13:45 0.50 311 94 INTRM1 DRILL PULD P UD HWDP & Collars 13:45 14:30 0.75 94 94 INTRM1 DRILL SRVY P Dn Load MWD 14:30 15:00 0.50 94 0 INTRM1 DRILL PULD P UD MWD, Mud Motor & Bit 15:00 15:30 0.50 0 0 INTRM1 CASIN( RURD P Pull Wear Bushing 15:30 16:00 0.50 0 0 INTRM1 CASIN( RURD P Clean and clear rig floor -Lay all tools do beaver slide 16:00 17:30 1.50 0 0 INTRM1 CASIN( RURD P PJSM running csg - RU 7 5/8" csg tools -Slips, elevators, long bails, ower ton s, Franks tool 17:30 17:45 0.25 0 0 INTRM1 CASIN( SFTY P PJSM hazards rolling csg -Safety meetin with roustabouts in i e shed 17:45 18:15 0.50 0 0 INTRM1 CASIN( RUNL P PU pups and tools from beaver slid 18:15 18:30 0.25 0 0 INTRM1 CASIN( SFTY P PJSM with floor crew on hazards while runnin cs 18:30 19:00 0.50 0 168 INTRM1 CASIN( RNCS P Run Jts 1 thru 4 -Check floats - "OK" 19:00 21:45 2.75 168 2,758 INTRM1 CASIN( RNCS P Con't running csg f/ 168' to 2758' MD - No roblems noted. 21:45 22:15 0.50 2,758 2,758 INTRM1 CASIN( CIRC P Circu csg volume @ surface shoe - 1253 stks 22:15 00:00 1.75 2,758 3,680 INTRM1 CASIN( RNCS P Con't running csg f/ 2758' MD to 3680' - Hole appears in good shape - No ti ht hole noted. 07/07!2006 00:00 00:15 0.25 3,680 3,680 INTRM1 CASIN( SFTY P PJSM -Crew change -review hazards runnin cs -. -.. ~ ~ ~~c ®f 22~j Time Logs i Date From To Dur th E. Depth Phase Code Subcode T ..OM 07/07/2006 00:15 02:15 2.00 3,680 6,962 INTRM1 CASIN( RNCS P Con't running 7 5/8" 29.7# L80 BCTM csg f/ 3689' to 6962' TD Shoe (162 jts + cut off #163) No problems running cs - No ti ht hole 02:15 03:15 1.00 6,962 6,962 INTRM1 CEMEf~ CIRC P Circu BU + w/ Franks Tool (2779 stks total) - PR 7 bpm, PP 670 psi. Recip cs 20' 03:15 03:45 0.50 6,962 6,962 INTRM1 CEMEI~ RURD P R/D Franks Tool -Blow do TD - R/U CMT head 03:45 05:45 2.00 6,962 6,962 INTRM1 CEME~ CIRC P Con't to Circu and condition mud for CMT - PR 7 bpm, PP 450 psi -Start properties MW 9.6 ppg, FV 56, PV 9, YP 27, 10 min gels 18 and the After cond = MW 9.1+, FV 42, PV 10, YP 10, 10 min els 6 05:45 07:45 2.00 6,962 6,962 INTRM1 CEMEI~ DISP P Cement 7 5/8" Csg, Pump 10 bbl CW100, Test lines to 3500 psi, pump 65 bbls, pump 75 bbls MudPush @ 12ppg, Drop bttm plug, pump 163 bbls tail cmt @ 12.5ppg, drop top plug, DS kick out w/ 2 bbls water. Rig displace with MOBM, 3127 stks, Bump Plug w/ 500 psi over to 1350 psi. Ck floats after 4 min "Held" - CIP 0730 hrs 07:45 08:00 0.25 6,962 6,962 INTRM1 CASIN( SFTY P PJSM -Review Slip setting procedures - Review known hazards 08:00 09:00 1.00 6,962 6,962 INTRM1 CASIN( RURD P P/U BOPs -RD CMT head -Clear tools from ri floor 09:00 10:30 1.50 6,962 6,962 INTRMI CASIN( NUND T Vetco/Gray set slips (planned). Had trouble with the first set of slips would not hold. Had to use and set second set of sli s. 10:30 12:00 1.50 6,962 6,962 INTRM1 CASIN( NUND P Cut Casing w/Pneumatic Cutter 12:00 12:15 0.25 6,962 6,962 INTRM1 CASIN( SFTY P PJSM - instgll packoff /Nipple up BOP inch oints 12:15 12:45 0.50 6,962 6,962 INTRM1 CASIN( RURD P Install pack off /Rig down casing tools and than a bales 12:45 13:45 1.00 6,962 6,962 INTRM1 CASIN( NUND P Nipple up BOP, test pack off @ 3800 si 10 min . Install wear rin . 13:45 15:00 1.25 6,962 6,962 INTRM1 CASIN( OTHR P 7-5/8" x 10-3/4" annulus infectivity test w/ 9.0 ppg WBM (11.8 ppg EMW). Pump 120 BBL fresh water flush @ 3 BPM IP 600 psi & FP 730 psi. Stop pump & stabilize @ 400 psi & shut in. Freeze Protected Annulus w/ 83 BBLs Diesel @ 2.5 BPM lP 400 psi & FP 700 si. 15:00 15:15 0.25 6,962 6,962 INTRM1 CASIN( SFTY P PJSM -cut & slip drill line (Hazard Reco nition 15:15 16:15 1.00 6,962 6,962 INTRM1 RIGMN SVRG P Cut & Slip drill line 72', inspect brakes, check C-O-M, Lube Top Drive & Blocks 16:15 21:15 5.00 6,962 6,962 INTRM1 DRILL TRIP P PU, drift, and RIH w/ 45 jts Hybrid DC, 21 jts HWDP, & 99 jts 4" DP w/ Su er-Sliders s.~~ Time Logs Date From To Dur th E. Depth Phase,, Code Subcode T QOM 07/07/2006 21:15 23:30 2.25 6,962 6,962 INTRM1 DRILL TRIP P POOH standing back drill string 23:30 00:00 0.50 6,962 6,962 INTRM1 DRILL RURD P Clean Rig Floor 07/08/2006 00:00 00:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on PU & MU BHA & 102 jts DP 00:15 01:15 1.00 0 96 INTRM1 DRILL PULD P PU & MU BHA #4, Motor, Float Sub, Stav, DM, SlimPhase 4, PWD, TM collar 96' MD 01:15 03:30 2.25 96 96 INTRM1 DRILL SRVY P Plug in & up-load MWD (Trouble w/ si nal 03:30 04:00 0.50 96 371 INTRM1 DRILL PULD P PU & MU 3 jts non mag DCs, 1 jt HWDP, Jars, 4 'ts HWDP 04:00 08:00 4.00 371 6,716 INTRM1 DRILL TRIP P TIH from 371' to 6716' MD by PU 102 jsts of 4" DP from pipe shed and 68 stds from derrick 08:00 08:30 0.50 6,716 6,875 INTRM1 DRILL REAM P Wash down from 6716' MD to 6875' MD. Tagged up @ 6875' MD w/ 10k- On de th for float collar 08:30 09:30 1.00 6,875 6,875 INTRM1 CASIN( DHEQ P Circu air from system -Preform casing Test 3000 si & chart for 30 min 09:30 11:15 1.75 6,968 6,993 INTRM1 DRILL DRLG P Drill float equipment & 25' of new hole to 6993' MD. PU = 103k, SO = 70k, Rot = 80k, TQ = 5k, ADT = .07, AST _ .07 11:15 12:00 0.75 6,993 6,993 INTRM1 DRILL CIRC P Circ. BU and until mud is uniform in and out for LOT 12:00 12:15 0.25 6,993 6,993 INTRM1 DRILL SFTY P PJSM -Leak off test (Pressure Hazards 12:15 13:00 0.75 6,993 6,993 INTRM1 DRILL FIT P Leak off test w/ 8.8 ppg, TVD 3628', OBM @ 15.9 ppg EMW. Blow down lines 13:00 00:00 11.00 6,993 7,660 PROD1 DRILL DDRL P Drill ahead from 6993' to 7660' MD (3658' TVD). AST = 1.02 hrs, ART = 6.82 hrs, ADT = 7.84 hrs, Jars (#14001358) = 7.91 hrs, PU = 135k, SO = 74k, ROT = 93k, TQ = 5k (on & off btm), ECDs = 10.13, Max Gas = 70 units, Kill rates w/ 8.7 ppg MW @ 7620' MD (3657' TVD): #1 Pump @ 30 spm = 700 psi, @ 40 spm = 910 psi; #2 Pump @ 30 spm = 650 psi, @ 40 spm = 880 psi. SLIDE Ftg (7107-7140' @ 150R), (7337-7348' @ 20R), (7348-7382' @ 34R), 7439-7479' @ 10 R). Concretion MDs (7035-7042'), (7190-7192'), (7274-7277'), 7482-7606' ... Total = 136' 07/09/2006 00:00 00:15 0.25 7,660 7,660 PROD1 DRILL SFTY P PJSM - On drlg ahead -Discuss pinch oints ~'c ~ oaf ~~ Time Logs _ Date From To _ Dur th E. De th Phase Code Subcode T OM 07/09/2006 00:15 12:00 11.75 7,660 8,170 PROD1 DRILL DDRL P Drlg w/ Motor f/ 7660' MD to 8170' MD ADT 9.09 hrs, Up wt 135k, Dn wt 80k, Rot wt 105k, Torq On Bttm 6k -Off Bttm 6k, ECDs 10.15, Max gas = 107 units, Jar hrs = 17 hrs. PR 298 gpm, PP 3300 psi, RPMs 80, WOB 10-15k. Concretions @ 7673' - 7706', 7730' - 7740', 7801' - 7812' , 7895' - 7940' Total 99' 12:00 12:15 0.25 8,170 8,170 PROD1 DRILL SFTY P PJSM - Drlg Ahead - BROOH hazards 12:15 14:00 1.75 8,170 8,281 PROD1 DRILL DDRL P Drlg w/ Motor f/ 8170' to 8281' MD / 3631' TVD, ADT 1.89 hrs, PR 300 m, PP 3200, RPMs 80, WOB 8-12k, 14:00 15:00 1.00 8,281 8,281 PROD1 DRILL CIRC P Get SPR -Pump up last Survey - CBU, Recip drill string full 90', PR 300 m. RPMs 80 15:00 16:30 1.50 8,281 6,898 PROD1 DRILL TRIP P POOH on elevators to 6898' MD small tight spots at 7435' & 7350') both wiped clean. These were noted to be set and slide area's. 16:30 17:15 0.75 6,898 6,898 PROD1 DRILL CIRC P Pump 30 sweep @ csg shoe. Pump, rotate and recip 90' stroke. PR 300 gpm, 70 RPMs -Sweep showed minimal increase in cutting -Hole a ears clean and in ood sha e. 17:15 18:15 1.00 6,898 8,281 PROD1 DRILL TRIP P RIH to 8258' MD -Precautionary wash to bttm 8281' MD / 3631' TVD. No tight hole noted - No fill 18:15 19:30 1.25 8,281 8,281 PROD1 DRILL CIRC P Pump 30 bbl Wt/Hi Vis sweep - Circu and condition, PR 300 gpm, 80 RPMs - Flow Ck well 19:30 20:15 0.75 8,281 8,281 PROD1 DRILL CIRC P CO well bore fluid to 8.7ppg SFOBM - Pump 123 bbls SFOBM -Displace w/ 62 bbls OBM including dry job -Drop 1.75" drift. 20:15 23:00 2.75 8,281 160 PROD1 DRILL TRIP P POOH on elevators - No tight hole - recoverdrift -Std bk HWDP w/ jars - LD MWD tools. 23:00 00:00 1.00 160 0 PROD1 DRILL SRVY P Down Load MWD 07!10/2006 00:00 00:15 0.25 90 90 PROD1 DRILL SRVY P Con't Down load MWD 00:15 00:30 0.25 90 90 PROD1 DRILL SFTY P PJSM- Discuss UD BHA and known hazards 00:30 01:00 0.50 0 0 PROD1 DRILL RURD P UD BHA - TM collar, PWD, Slimephase 4, DM HOC, Stab, NM Flt Sub, Motor, Bit 01:00 01:30 0.50 0 0 COMPZ DRILL RURD P Clear & Clean Rig Floor 01:30 01:45 0.25 0 0 COMPZ CASIN( SFTY P PJSM - on Rigging up & running 4.5" slotted liner 01:45 03:30 1.75 0 2,040 COMPZ CASIN( RUNL P PU & MU 48 jts of 4.5" slotted liner 03:30 04:00 0.50 2,040 2,040 COMPZ CASIN( PUTB P PU & MU seal bore ext., liner hanger, C2 ZXP liner to acker _.~ - Pace ~ ~f ~2 Time Logs ~ Date From To Dur ? . a th E. De th Phase Code Subc ' CCM 07/10/2006 04:00 07:30 3.50 2,040 8,282 COMPZ CASIN( RUNL P Cont. RIH with 4.5" liner on DP to 8282' MD. Tagged up w! 20k down wei ht 07:30 08:15 0.75 8,282 8,275 COMPZ CASIN( DHEQ P PU to 8275' MD, PU = 148k, SO = 85k, Drop ball and pump down @ 3 BPM & 500 psi. Pressure up to 2500 psi to set hanger, 4000 psi to set packer, back out of setting tool with 15 turns to the right, PU = 134k, SO = 90k 08:15 09:30 1.25 8,275 3,561 COMPZ DRILL TRIP P Flow check well (static), POOH from 6150' to 3561' MD 09:30 10:30 1.00 3,561 3,561 COMPZ RIGMN RGRP T Hydraulic power unit line Leak ... Fix same 10:30 12:00 1.50 3,561 0 COMPZ DRILL TRIP P Continue POOH from 3561' to surface 12:00 12:15 0.25 0 0 COMPZ DRILL SFTY P PJSM on UD running tools (proper ri in of overhead loads 12:15 13:00 0.75 0 0 COMPZ DRILL RURD P Brreak & UD running tools, clean rig floor monitor well on tri tank 13:00 13:30 0.50 0 0 COMPZ RIGMN SVRG P Service rig, top drive, drawworks couplings, override clutch & drum s ear 13:30 14:15 0.75 0 0 COMPZ EVAL1l~ RURD P Spot SWS logging unit & off load tools 14:15 14:30 0.25 0 0 COMPZ EVALVI~ SFTY P PJSM on PU & RU wireline tools & USIT to in Pinch Points 14:30 16:00 1.50 0 0 COMPZ EVAL1l~ RURD P RU wlretire & PU' USIT tools 16:00 17:30 1.50 0 0 COMPZ EVALV~ DHEQ P Calibrate & Check equipment 17:30 20:15 2.75 0 6,150 COMPZ EVALV~ ELOG P RIH w/ USIT tools (begin to tractor down @ 18" 30 hrs from 5130' MD to 6150' MD Schlumber er Tractor. 20:15 22:30 2.25 6,150 4,000 COMPZ EVAL1l~ FLOG P Logging from 6150-4000' MD 22:30 23:00 0.50 4,000 0 COMPZ EVALVI~ FLOG P POOH 23:00 00:00 1.00 0 0 COMPZ EVALVI~ RURD P Rig down wireline & lay down USIT tools. Well monitored -Static. 07/11/2006 00:00 00:15 0.25 0 0 COMPZ EVAL1l~ RURD P Continue LD Cement /Corrosion to in tools. 00:15 00:30 0.25 0 0 PROD2 DRILL SFTY P PJSM for PU/MU whipstock assembly. 00:30 02:15 1.75 0 107 PROD2 STK WPST P PU/MU anchor, whipstock /mill, seals, stop sub, unloader, 3-1/2" HWDP, pups, blank sub, trip anchor, safety disconnect, drain sub, debris catcher, lower water mellon mill, flex joint, string mill, 3-1/2" HWDP, float sub, MWD. 02:15 03:00 0.75 107 107 PROD2 DRILL SRVY P Upload MWD. 03:00 03:30 0.50 107 479 PROD2 STK WPST P Continue PU Bumper sub, XO and 3 stds of 4" x 4-3/4" h brid ush i e. Time Los Date From To Dur th E De th Phase Code Subcode T OM 07/11/2006 03:30 03:45 0.25 479 479 PROD2 DRILL DHEQ P Shallow test MWD at 285 GPM and 1,075 si - oka . 03:45 06:00 2.25 479 5,220 PROD2 STK WPST P RIH from 479' - 5,220'. 06:00 06:45 0.75 5,220 5,270 PROD2 STK WPST P Make correlation MAD pass of K-13 from 5,250-70' tmd, at 295 gal and 2,060 si. 06:45 07:30 0.75 5,270 6,148 PROD2 STK WPST P Continue TIH from 5,270 - 6,148'. 07:30 07:45 0.25 6,148 6,072 PROD2 STK WPST P Orient whipstock to 14 deg left, PU = 130K, SO = 90K. Set whipstock. Top of whi stock at 6,072' tmd. 07:45 12:00 4.25 6,072 6,085 PROD2 STK WPST P Mill B-lateral window. Pump 30 bbl ~"' /~~ ~G% i 1.,, . Hi-Vis sweep at 6,080'. TOW= 6,072' BOW= 6,085' 12:00 12:15 0.25 6,085 6,085 PROD2 DRILL SFTY P PJSM for milling. 12:15 13:00 0.75 6,085 6,111 PROD2 STK WPST P Drill new hole from 6,085-6,111' tmd, with 6-3/4" full guage hole to 6,095'. Pum 30 bbl Hi-Vis swee . 13:00 14:00 1.00 6,111 6,111 PROD2 DRILL CIRC P Circulate sweep out of hole at 300 GPM, 120 RPM, reciprocating pipe from 6,111 - 6,065' and working string mills throu h window. 14:00 15:45 1.75 6,111 479 PROD2 DRILL TRIP P POOH with milling assembly. 15:45 16:30 0.75 479 4,060 PROD2 DRILL PULD P LD Bumper sub and download MWD 16:30 17:00 0.50 4,060 0 PROD2 DRILL PULD P LD MWD and milling assembly. Upper mill in au e. 17:00 18:15 1.25 0 0 PROD2 DRILL OTHR P Pull WB, flush stack, set WB and clean ri floor. 18:15 19:00 0.75 0 91 PROD2 DRILL PULD P PU/MU drilling assembly with 6-3/4" Concretion bit, 5" motor, float sub and MWD. Orient MWD. 19:00 19:30 0.50 91 91 PROD2 DRILL SRVY P Upload MWD. 19:30 20:15 0.75 91 1,762 PROD2 DRILL DHEQ P RIH 15 stds to 1,762', shallow test MWD: 260 GPM = 1,630 psi, 300 GPM= 2,100 si. 20:15 21:00 0.75 1,762 1,873 PROD2 DRILL DHEQ P PU AGI-tater, shock sub and RIH to std #16 at 1,873'. Shallow test AGI-tater and MWD: 260 GPM= 2,100 psi, 300 GPM= 2,650 psi. AGI-tater pressure increase = +/- 550 si. 21:00 22:00 1.00 1,873 5,980 PROD2 DRILL TRIP P Continue RIH to 5,980' filling DP at 5,048' and 5,980'. 22:00 22:15 0.25 5,980 5,980 PROD2 DRILL SFTY P PJSM for cut and slip DL. 22:15 23:15 1.00 5,980 5,980 PROD2 RIGMN SVRG P Cut and slip 48' of DL. Inspect brakes, check Saver sub, tube blocks and Top Drive. a .____ P~ ~ 1 ~f Time Logs_ a -- Date From To Dur ~ th E. De th Phase Code Subcode T OM 07/11/2006 23:15 00:00 0.75 5,980 6,095 PROD2 DRILL TRIP P Break circ orient to 10L and wash to 6,065' tmd. Slide to 6,085'. Slide and ream to 6,095'. PU=98K, S0= 70K. 07/12/2006 00:00 12:00 12.00 6,095 6,919 PROD2 DRILL DDRL P Directionally drill 6-3/4" B-lateral from 6,095' - 6,919' tmd (3,488') ADT= 6.87, ART= 5.15, AST= 1.72 PU= 104K, S0= 65K, ROT= 83K TQ on/off = 5,000 / 4,000 ft-Ib ECD= 9.92 ppg Max Gas= 71 umits Concretions: 6,118-124', 6,154-161', 6,263-278', 6,309-332', 6,349-370', 6,372-379', 6,390-397' = 83' 12:00 00:00 12.00 6,919 8,010 PROD2 DRILL DDRL P Directionally drill6-3/4" B-lateral from 6,919' - 8,010' tmd (3,487') ADT= 8.54, ART= 5.80, AST= 2.74 PU= 118K, S0= 58K, ROT= 83K TO on/off = 5,000 / 4,500 ft-Ib ECD= 10.38 ppg Max Gas= 150 umits Concretions: 6,988-996', 7,389-397', 7,492-511', 7,528-540', 7,586-601', 7,661-668', = 69' 07/13/2006 00:00 09:00 9.00 8,010 8,988 PROD2 DRILL DRLG P PJSM. Drill 8,010 - 8,988' and (3,448' tvd). ADT= 5.8, AST= 1.52, ART= 4.28 09:00 10:00 1.00 8,988 8,998 PROD2 DRILL CIRC P Pump 35 bbl weighted Hi-Vis sweep @ 302 GPM, 3,600 psi and 100 rpm. Had 25% increase in cutting returns. Evaluate eolo 10:00 12:00 2.00 8,998 9,115 PROD2 DRILL DRLG P Drill ahead from 8,988-9,115' and (3,445' tvd). ADT= 0.77, AST= 0.13, ART= 0.54 PU= 125K S0= 45K ROT= 82K ECD= 10.77 ppg Max Gas= 127 units 12:00 13:30 1.50 9,115 9,248 PROD2 DRILL DRLG P Drill ahead from 9,115-9,248' and (3,432' tvd). ADT= 1.19, AST= 0.25, ART= 0.94 PU= 125K S0= 45K ROT= 82K ECD= 10.77 ppg Max Gas= 127 units 13:30 14:30 1.00 9,248 8,788 PROD2 DRILL REAM T POOH to 8,860' with 50K over uII.BROOH 8,845-8,788'. 14:30 15:45 1.25 8,825 8,832 PROD2 DRILL DDRL T Sidetrack &{aural, tt'oughing,;-nd 3- drilling from$,825-8,832'. KOP @8,825' and AST= 1.25 hr. 15:45 16:00 0.25 8,832 8,850 PROD2 DRILL DDRL T Drill sidetrack hole from 8,832-8,850' md. AST= 0.18 hr Time Logs Date From To Dur th E. De th Phase Code Subcode T _ OM 07/13/2006 16:00 16:30 0.50 8,850 8,850 PROD2 DRILL SRVY T Take check shot surveys. Orient toolface for slide drillin . 16:30 21:00 4.50 8,850 9,248 PROD2 DRILL DRLG T Drill ahead from 8,850' - 9,248' and , ADT= 4.43 21:00 00:00 3.00 9,248 9,371 PROD2 DRILL DRLG P Drill from 9,248-9,371' and (3,452' tvd) ADT= 0.70, AST= 0.22, ART= 0.48 07/14/2006 00:00 12:00 12.00 9,371 10,200 PROD2 DRILL DRLG P PJSM. Drill ahead B-lateral from 9,371-10,200' tmd (3,431' tvd) ADT= 8.0, AST= 2.69, ART= 5.31 hrs PU= 135K S0= 60K ROT= 94K TQ on/off = 6,500 / 6,500 ft-Ib ECD= 10.8 ppg Max Gas= 153 units Concretions: 9,372-378', 9,412-16', 9,492-501', 9,710-12', 9,778-87', 9,792-9,800', 10,013-020' 12:00 00:00 12.00 10,200 11,261 PROD2 DRILL DRLG P PJSM. Drill ahead B-lateral from 10,200-11,261' tmd (3,431' tvd) ADT= 6.67, AST= 1.67, ART= 5.0 hrs PU= 135K S0= 60K ROT= 94K TO on/off = 6,500 / 6,500 ft-Ib ECD= 10.8 ppg Max Gas= 153 units Concretions: 10,249-258', 10,365-366', 10,472-475', 10,546-550', 10,646-649' 07/15/2006 00:00 12:00 12.00 11,261 12,252 PROD2 DRILL DRLG P Drill ahead B-lateral 11,261' - 12,252' tmd (3,409) Pump 30 bbl Hi-Vis sweep at 11,550', with a 15% increase in cutting returns. ADT= 6.85, ART= 5.47, AST= 1.38 hrs, PU= 155K, S0= 47K, ROT= 100K, TQ on/off = 9,000 / 9,000 ft-Ib, Max Gas= 130 units, ECD= 11.16 ppg Concretions: 12,020-033', 12,049-055', 12,120-124', 12,142-150' 12:00 21:15 9.25 12,252 12,963 PROD2 DRILL DRLG P Drill ahead B-lateral 12,252' - 12,963' tmd (3,407) Pump 30 bbl Hi-Vis sweep at 12,930'. ADT= 5.67, ART= 4.09, AST= 1.58 hrs, PU= 15K, S0= 35K, ROT= 100K, TQ on/off = 10,000 / 10,000 ft-Ib, Max Gas= 70 units, ECD= 11.27 ppg, Concretions: 12,020-033', 12,049-055', 12,120-124', 12,142-150' 21:15 22:30 1.25 12,963 12,963 PROD2 DRILL CIRC P Circ sweep out while reciprocating pipe with 90 rpm and 278 gpm. Had a 5% increase in cutting returns. Monitor well -static. Surve at TD. 22:30 22:45 0.25 12,963 12,963 PROD2 DRILL SFTY P PJSM for BROOH. 22:45 00:00 1.25 12,963 12,277 PROD2 DRILL REAM P BROOH from 12,963' - 12,277' at 90 rpm, 45-50 ft/min, 278 gpm and 4,000 si. ®.e e~ ®~ _°°® _ ~t~~ 7 ~f ~~ ~ ~~.. ~. ~ . .~ Time Los Date From To Dur ~ th E. De th Phase Code Scibcode T QOM 07/16/2006 00:00 07:45 7.75 12,277 5,985 PROD2 DRILL REAM P BROOH from 12,277 - 6,085' md, at 90 rpm, 278 gpm, 40-45 ft/hr. Max overpull 10-12K. Pull thru window with pumps off, no problem. Hole unloading a "moderate" amount of sand while BROOH from 7,000' - 6,085'. 07:45 09:00 1.25 5,985 5,985 PROD2 DRILL CIRC P Pump 30 bbl weighted Hi-Vis sweep. Circ 3x btms up at 5,985' with 300 gpm, 3,000 psi, 40 rpm, TQ=4,000 tt-Ib. Had a 10% increase in cuttings returns when um in swee . 09:00 10:00 1.00 5,985 5,985 PROD2 RIGMN SVRG P Service TD and inspect saver sub. 10:00 11:00 1.00 5,985 6,825 PROD2 DRILL TRIP P RIH through window w/o problems. PU 105K, S0= 65K. 11:00 13:30 2.50 6,825 12,425 PROD2 DRILL TRIP P PJSM. RIH to 12,140', filling pipe at 8,788' and 11,560'. Ream from 12,140-184'. Continue RIH to 12,425 with slackoff weight decreasing from 45K-34K block wei ht . 13:30 14:30 1.00 12,425 12,963 PROD2 DRILL REAM P Ream from 12,425' to TD at 90 rpm, 271 gpm and 3,900 psi and 45-50 ft/min. Tag btm, set back stand and PU single to be able to reciprocate i e. 14:30 16:00 1.50 12,963 12,963 PROD2 DRILL CIRC P Pump 30 bbl Hi-Vis sweep. Circulate and reciprocate pipe with 90 rpm, 278 gpm and 4,000 psi (pressure limit). Sweep returned 10% increase in cuttings. Monitor well -static. PU=170K, S0=34K, ROT=100K. 16:00 17:15 1.25 12,963 12,963 PROD2 DRILL CIRC P Pump and displace open hole 325 bbl of 8.7 SFMOBM. 17:15 22:30 5.25 12,963 250 PROD2 DRILL TRIP P LD single and POOH to AGI-tater and shock sub, LD same. Continue POOH, stand back HWDP, jars and flex collars. 22:30 00:00 1.50 250 50 PROD2 DRILL SRVY P Download MWD. Max Gas= 78 units 07/17/2006 00:00 01:00 1.00 50 50 PROD2 DRILL PULD P Continue downloading MWD. 01:00 01:30 0.50 50 0 PROD2 DRILL PULD P Continue LD BHA, break bit, and LD motor. 01:30 02:00 0.50 0 0 COMPZ DRILL OTHR P Pull WB 02:00 05:30 3.50 0 0 COMPZ DRILL OTHR P RU pressure test equipment, chit recorder and test BOPE to 250 psi / 3,000 psi hi/low, holding for 5 minutes of stabilized pressure. Test upper pipe rams, choke valve manifold valves number 1, 12, 13 and 14, manual kill line, upper IBOP, HCR Kill, choke manifold valves #5,8 and 10, Dart valve, CV No. 4,6,7, floor valve, CV 2, HCR, Annual reventer, and Blind rams. 05:30 06:00 0.50 0 0 COMPZ DRILL OTHR P RD test equipment, install WB. ~ ~ i~~c~~ 9~ ~ ® ~ ..~ Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 07/17/2006 06:00 07:00 1.00 0 0 COMPZ CASIN( RURD P Clean rig floor and RU liner running tools. 07:00 11:30 4.50 0 6,053 COMPZ CASIN( RNCS P PJSM. Run 140 joints of Blank / Slotted, 11.6 Ib/ft, L-80, BTC liner with torque rings installed and 4-1/2" x 6-3/8" Hydroform centralizers on each joint with Stop collars on the center of each 'oint. 11:30 12:30 1.00 6,053 6,693 COMPZ CASIN( RNCS P PJSM. Finish running 155 joints of Blank !Slotted, 11.6 Ib/ft, L-80, BTC liner with torque rings installed. PU= 82K, S0= 60K, ROT= 65K, TQ=3,000 ft-Ib at 10 and 20 rpm. RD liner runnin tools, clean ri floor. 12:30 16:30 4.00 6,693 12,925 COMPZ CASIN( RUNL P PU/MU 5-1/2" receptacle, Liner setting sleeve and running tool, continue running liner on 4" DP to 12,608' and where SO weight = 0. Commence rotating liner down, working through tight spot @ 12,802'. Continue rotating liner until tagging bottom at 12, 959' md. PU and locate liner shoe on depth at 12, 925'. PU=175K, S0= OK, ROT= 97K, TQ= 10,000 ft-Ib at 20 r m. 16:30 17:15 0.75 12,925 6,032 COMPZ CASIN( RUNL P Drop ball and pump down to ball seat, pressure up to 2,000 psi and release liner. Pressure up to 4,400 psi and shear out Circ sub. PU= 135K. PU and tag top of liner, confirming TOL at 6,238'. POOH with running tool to 6,032' 17:15 18:00 0.75 6,032 6,032 COMPZ CASIN( CIRC P CBU. Monitor well -static. Pump slug. 18:00 20:00 2.00 6,032 200 COMPZ CASIN( RUNL P POOH with displacement 6 bbl over Had lost 6 bbl whilst testin BOPE 20:00 20:15 0.25 200 0 COMPZ CASIN( OTHR P Inspect-ok, and LD liner running tools. 20:15 20:45 0.50 0 50 COMPZ FISH PULD P PU/MU whipstock retrieving fishing tools 20:45 22:45 2.00 50 6,115 COMPZ FISH TRIP P RIH to 6,068 filling DP at 3,130' and 6,068'. PU single, PU= 125K, S0=82K. Break circ. 22:45 23:30 0.75 6,100 6,100 COMPZ FISH FISH P Wash across whipstock slot, and attem t to hook. 07/18/2006 00:00 02:15 2.25 6,077 6,077 COMPZ FISH JAR P Attempt and Hook Whipstock @ 6,077'. 02:15 02:30 0.25 6,077 5,975 COMPZ FISH TRIP P UD 1 jt. 4" DP Rack back 1 stand DP Pick u wt. 130k-145K. 02:30 03:30 1.00 5,975 5,975 COMPZ FISH CIRC P CBU @ 5975' 48 spm 173 gpm 850 psi Max as B/U 51 units. 03:30 07:30 4.00 5,975 100 COMPZ FISH TRIP P Monitor well & pump dry job. POH P/U 130k-135k Calculate for trip out 51 bbls. Actual 55 bbls. P 9 r ~sf ~2 Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 07/18/2006 07:30 08:30 1.00 100 0 COMPZ FISH PULD P PJSM-Lay down BHA Whipstock & Trip anchor assembly,2 3.5" pups 1 jt. 3.5" HWDP & seal assembl . 08:30 09:15 0.75 0 0 COMPZ FISH OTHR P Clean & clear rig floor. 09:15 10:15 1.00 0 0 COMPZ RIGMN SVRG P PJSM- Slip & cut 66' Drlg. line. 10:15 10:45 0.50 0 0 COMPZ RPCOCv PULD P P/U Baker &MWD slimhole tools. 10:45 11:15 0.50 0 0 COMPZ RPCOh PULD P R/U Csg. Equipment. 11:15 12:00 0.75 40 40 COMPZ RPCOh RCST P P/U Shoe jt. 1 jt. 4.5" tbg. 12:00 12:15 0.25 40 213 COMPZ RPCOCV RCST P PJSM-on P/U Hook hanger (Pinch points, good comunications,Remjnder sto ro ram. 12:15 14:15 2.00 213 300 COMPZ RPCOCV RCST P P/U & M/U Hook hanger/MWD assembly, running tool &RIH (SPT @ 300' 14:15 16:30 2.25 300 6,207 COMPZ RPCOR TRIP P RIH tag main bore XO @ MD 6207'-P/U wt. 135k S/O wt. 84k. 16:30 18:15 1.75 6,207 6,283 COMPZ RPCOCV TRIP P Pull up to 6060'-rotate 6 revs. & work torque-enter window & TO 6261-orient tool face & hook @ 6087' @ 7L stack 40k-pull up w/ hook @ 6060' turn 180 deg. S/O & tag XO @ 6290'-P/U to hook @ 6060' & reorient TF 0-S/O & hook @ (MD 6087 & Stack 45k TF 7L) w/shoe MD 6283'. 18:15 19:00 0.75 6,283 6,283 COMPZ RPCOh DHEQ P Drop & Pump ball on seat-Press. up 2000 psi increase to 2700 psi shear & inflate packer w/ 4 stks (14.2 gal).-shear out circ. sub w/ 4500 si-monitor well-Static-POOH to 6038'. 19:00 19:45 0.75 6,283 6,283 COMPZ RPCOh CIRC P CBU (Max gas units 57) Monitor well-static- um slu . 19:45 21:45 2.00 6,283 120 COMPZ RPCOh TRIP P POOH -Displacement 1.25 bbls. long. 21:45 23:00 1.25 120 0 COMPZ RPCOh PULD P Lay down running tools &MWD assembl . 23:00 23:30 0.50 0 0 COMPZ RPCOh RURD P Clear & clean rig floor of tools. 23:30 00:00 0.50 0 0 COMPZ RIGMN SVRG P Rig service-tube crown,blocks & Top Drive. 07/19/2006 00:00 00:30 0.50 0 0 COMPZ RPCOh SFTY P PJSM-Rig up csg. Equipment 00:30 02:30 2.00 0 477 COMPZ RPCOh PULD P M/U Lem assembly, Bent jt. w/ seals, 1 jt. 4 1/2" tbg. DB-6 nipple 3 pup jts. 7 jts. IBT 4.5" tbg.CSBR, ZXP w/ runnin tool & XO. 02:30 05:30 3.00 477 6,070 COMPZ RPCOh TRIP P RIH w/ LEM assembly P/U 140k S/O 88k. Latch @ 6070' w/ Seal Assembly @ 6197.62' (10.21' Inside A2 CSR). Pull 160k-unlatch to verify. Relatch LEM & ull 150k. P~~~~~ 96 of ~ Time Los Dafe From To Dur ~ th E. De th Phase ode Subcode T OM 07/19/2006 05:30 06:00 0.50 6,070 6,070 COMPZ RPCOh OTHR P Drop ball & pump down @ 3 bpm 400 psi.; Ball on seat @ 455 strokes.Set ZXP pressure to 2200psi. Pressure to 4000 si release LEM. 06:00 06:30 0.50 6,070 6,070 COMPZ RPCOh OTHR P Test ZXP down annulus to 1000 f/ 10 min on chart OK. 06:30 07:15 0.75 6,040 6,040 COMPZ RPCOh CIRC P Pull up to 6040-CBU @ 80 spm 1500 si 37 units as on B/U. 07:15 09:30 2.25 6,040 0 COMPZ RPCOh TRIP P Monitor well-pump dry job & POH. 09:30 10:00 0.50 0 0 COMPZ RPCOti OTHR P Lay down liner running tools. 10:00 10:30 0.50 0 0 COMPZ RPCOh OTHR P Clear & clean floor & pick up tools. 10:30 12:00 1.50 0 0 PRODS FISH PULD P PJSM-make up mill assembly. NO w/ seals-unloader sub & 1 't. 3.5" DP. 12:00 12:15 0.25 0 0 PRODS FISH PULD P PJSM-on pick up milling & Whipstock assembl . 12:15 13:00 0.75 0 200 PRODS FISH PULD P P/U & M/U Whipstock, mill & MWD assembly (Orient) & pick up bumper sub. 13:00 13:30 0.50 200 200 PRODS FISH PULD P Program MWD. 13:30 16:00 2.50 200 5,050 PRODS FISH TRIP P RIH (SPT@ 477) Fill dp @ 3280 cont. RIH to 5050' & break circ. 16:00 16:30 0.50 5,050 5,140 PRODS FISH TRIP P Mad pass from 5050 to 5140'. 16:30 17:00 0.50 5,140 5,801 PRODS FISH TRIP P RIH to 5755-break circ. P/U 125k S/O 85k-tag 5801'-shear anchor w/ 25k & Set whipstock @ 16 deg Left of :~ (P ` ~ Highside -confirm w/ 5k overpull-slack h- off & shear off whipstock w/ 45k RT wt 100k 80 r mt 3-5k 256 m 1750 si. 17:00 22:30 5.50 5,697 5,711 PRODS FISH MILL P Mill L-2 window from5697 to 5711. 22:30 00:00 1.50 5,711 5,720 PRODS FISH MILL P Mill new hole from 5711 to 5720'. 07/20/2006 00:00 00:45 0.75 5,720 5,741 PRODS FISH MILL P Continue to drill gauge hole from 5720' t0 5741'. 00:45 01:45 1.00 5,741 5,741 PRODS FISH CIRC P Pump 30 bbls. weighted hi-vis sweep-work mills thru window w/ pumps & rotation & without pumps & rotation. No problems. P/U 125k S/O 95k. 01:45 03:00 1.25 5,741 3,461 PRODS FISH TRIP P Monitor well-SPR-Pump dry job & poh to 3461'. 03:00 06:45 3.75 3,461 0 PRODS FISH TRIP P PJSM-Rig up & relocate supersliders on drill i e while POH. 06:45 07:00 0.25 0 0 PRODS FISH PULD P Lay down BHA-XO & Bumper sub. 07:00 07:15 0.25 0 0 PRODS FISH PULD P Down load MWD. 07:15 08:00 0.75 0 0 PRODS FISH PULD P Continue lay down BHA-upper mill was in au e. 08:00 08:15 0.25 0 0 PRODS FISH OTHR P Clear & clean rig floor. -~ Pad 9 ~f ;d2 .- ~~ Time Logs _ Date From To Dur th E. De th Phase Code Subcode T OM 07/20/2006 08:15 09:15 1.00 0 0 PROD3 FISH OTHR P Pull wear bushing-flush bop stack-run wear bushin . 09:15 11:00 1.75 0 100 PROD3 DRILL PULD P PJSM-Make BHA #8. 11:00 12:00 1.00 100 100 PROD3 DRILL PULD P Upload MWD. 12:00 12:15 0.25 100 100 PROD3 DRILL SFTY P PJSM-On Tripping & Drlg. 12:15 12:30 0.25 100 365 PROD3 DRILL TRIP P RIH w/ BHA #8 to 365'. Break in eo- ilot S.P.T. & command test. 12:30 14:00 1.50 365 5,691 PROD3 DRILL TRIP P RIH to 5691'-break circ. 270 gpm 1700# P/U 98k S/O 70k.RW 84k TQ 4k. 14:00 14:30 0.50 5,691 5,741 PROD3 DRILL CIRC P Wash & Slide from 5691 to 5731'- & ream 5731 to 5741'. 14:30 00:00 9.50 5,741 6,400 PROD3 DRILL DDRL P Drilling from 5741' to 6400' (TVD 3434') Actual Rotatin Time 6.63 Hrs. 07/21/2006 00:00 12:00 12.00 6,400 7,430 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole from 6400' to 7430'. (3435 ND) P/U 110k S/O 60k ROT 80k TQ 5.5k Max gas 134 units ECD 10.26 SPR @ Concretion depths 6497'-6501', 6505'-6506', 6514'-6517', 6554'-6556', 7064'-7067', 7139'-7141', 7172'-7175', 7178'-7190', 7199'-7203', 7357'-7363', 7380'-7387', 7389'-7397',. 12:00 00:00 12.00 7,430 8,430 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole from 7430' to 8430'. (3408 ND) P/U 115k S/O 50k ROT 78k TO 6k Max gas 125 units ECD 10.5 SPR @ Concretion depths 7412-7418-7500-7507-7550-7569-7571- 7588-7844-7849-7863-7872-7874-7876- 7881-7888-7905-7907-7910-7911-7995- 8002-8005-8063-8064-8067-& 8068. 07/22/2006 00:00 12:00 12.00 8,430 9,985 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole From 8430' to 9985'. (TVD 3365'.) ART-8.07 P/U 127k S/O 35k ROT 77k TQ on 7k TQ off 7.5k Max gas 363 units ECD 11.07 C oncretions=8620-8621-8625-8626-87 21-8724-8733-8736-8753-8756-9185- & 9188. 12:00 00:00 12.00 9,985 11,508 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole From 9985' to 11508'. (ND 3337') ART 7.38 P/U 137k S/O 0 ROT 82k TQ on 8.5k TQ off 8.5k Max gas 118 units ECD 11.45 Concretions 10435-10440-10732-10733-10744-1074 5-10750-10751-10763-& 10765'. 07/23/2006 00:00 07:30 7.50 11,508 12,285 PROD3 DRILL DDRL P Drlg. Horizontal .hole from 11508 to 12285'. (ND) 3345'. (777') ART 4.61 WOB 5-15K, RPM 135, Pu 160K, Dn OK, ROT 98K, TQ 9.5K on / 8.5K off, Max gas 289 units, Ave ECD's 11.8 07:30 08:15 0.75 12,285 12,285 PROD3 DRILL DHEO T Trouble shoot MWD. Change Mode. t~~g~ .~ ~~ ~~ Time Logs Date From To Dur th E. De th F'hase Code Subcode T OM 07/23/2006 08:15 10:45 2.50 12,285 12,566 PROD3 DRILL DDRL P Drlg. Horizontal hole from 12285' to 12566'. (TVD) 3330' (281'). ART 1.45 P/U 160k S/O 0 Rot 98k TQ on 9.5k Off 8.5k Max as 289 units ECD 11.8 10:45 11:00 0.25 12,566 12,566 PROD3 DRILL OTHR P SPR,s Lay Down Jt. 4" DP. 11:00 12:00 1.00 12,566 12,566 PROD3 DRILL CIRC P Pump 30 bbls. weighted hi-vis sweep @ 12562' @ 83 spm 3370 psi 135 rpm T 8k. 12:00 12:30 0.50 12,566 12,566 PROD3 DRILL CIRC P Circ. sweep out @ 83 spm 3370psi 135 r m 8k TQ "0" increase in returns. 12:30 12:45 0.25 12,566 12,566 PROD3 DRILL OTHR P Monitor well-Static-install stripping rubbers. 12:45 21:30 8.75 12,566 12,566 PROD3 DRILL TRIP P BROOH f/ 12,565' MD 3330 TVD to window @ 5711 MD @ 120 rpm 85 spm 310 gpm 3050 psi tq 7k pulled @ 40-45 FPM Calc displacement 45 bbls. Actual dis lacement 58.4 bbls. 21:30 21:45 0.25 12,566 12,566 PROD3 DRILL OTHR P Monitor well inside window-Static- Pull stri in rubbers. 21:45 00:00 2.25 12,566 12,566 PROD3 DRILL CIRC P Break circ. pump 35 bbls weighted hi-vis sweep @ 275 gpm till thru mwd , increase rate to 300 gpm 100 rpm, 2100 psi, 10% increase in returns, circulate shakers clean @ 3-bottoms u. 07/24/2006 00:00 01:00 1.00 12,566 5,600 PROD3 DRILL OTHR P PJSM=Cut 91' drlg. line, Service top drive & ins ect saver sub. 01:00 03:15 2.25 5,600 10,127 PROD3 DRILL TRIP P RIH, slide thru window-no problems, RIH to 10127' ran out of down wei ht. 03:15 06:00 2.75 10,127 12,560 PROD3 DRILL TRIP P Wash & ream in hole from 10127' to 12560' @ 77 spm 280 gpm 50 rpm 2500 si TQ 6k. 06:00 07:30 1.50 12,560 12,560 PROD3 DRILL CIRC P Pump 30 bbls. weighted hi-vis sweep 310 gpm 85 spm 120 rpm 3560 psi TQ 8.5k ECD 11.58 total gas 30 units 10% increase in cuttings on BU w/ swee . 07:30 08:45 1.25 12,560 12,560 PROD3 DRILL CIRC P Pump 320 bbls. 8.7# SFOBM, Displace w/ 50 bbls. OBM including d 'ob. 08:45 12:00 3.25 12,560 7,652 PROD3 DRILL TRIP P Monitor well, POH w/25-30k 175k P/U. 25-30k drag from 11970. (NOTE) Ramp on geo-pilot stuck @ 60deg. reflection. POH to 7652' P/U 125k S/O 52k. 12:00 14:45 2.75 7,652 0 PROD3 DRILL TRIP P POH on elevators from 7652' No roblems ullin thru window. 14:45 15:45 1.00 0 0 PROD3 DRILL PULD P Lay down hwdp, jars & 3 moneys. 15:45 16:30 0.75 0 0 PROD3 DRILL OTHR P Down load MWD. 16:30 17:45 1.25 0 0 PROD3 DRILL PULD P Pull up, Break bit, lay down MWD & Geo- ilot. 17:45 18:15 0.50 0 0 COMPZ DRILL OTHR P Clear & clean rig floor. ~e 7 oaf ~ ~~~ _~., ..~~ Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 07/24/2006 18:15 18:45 0.50 0 0 COMPZ CASIN( RURD P Rig up to run 4 1/2" slotted liner in "D" Lateral. 18:45 23:00 4.25 0 6,629 COMPZ CASIN( RUNL P PJSM=Run 4 1/2" liner to 6629', went thru window w/ no problems. Calc. displacement 27.7 Actual dis lacement 15.8 bbls. 23:00 23:30 0.50 6,629 6,629 COMPZ CASIN( PUTB P Change out handling tools=make up liner settin tool. 23:30 00:00 0.50 6,629 6,629 COMPZ CASIN( PUTS P Rig down csg. tools, rig up to run liner on 4" dp. P/U Jt. #154 82k S/O Jt. 154 58k. 07/25/2006 00:00 03:45 3.75 6,629 12,566 COMPZ CASIN( RUNL P Rotate liner @ 6730' 20 rpm TQ 3.5k=Run 4.5" slotted liner on 4" dp from 6629' to 12,566'=tag bottom P/U 170k S/O 45k. 03:45 04:00 0.25 12,566 12,551 COMPZ CASIN( RUNL P Pull up, rotate liner 20 rpm w/ 9K ft/Ib Torque, S/O tag bottom pull up to 12551.0 04:00 04:45 0.75 12,551 12,551 COMPZ CASIN( RUNL P Drop ball-set liner on depth while rotating. Pump down @ 4bpm saw no indication of ball seating after 1250 strokes. Shut down pumps. Mechanicaly released from liner 10k dro P/U 125k. 04:45 05:30 0.75 12,551 5,711 COMPZ DRILL CIRC P Pull 2 stands dp=CBU-wash whipstock slot from 5697-5711 @ 72 spm 1400 si 275 m. 05:30 08:00 2.50 5,711 0 COMPZ DRILL TRIP P Monitor well & POH. 08:00 08:30 0.50 0 0 COMPZ DRILL PULD P Lay down liner running tool & clean floor. 08:30 09:30 1.00 0 0 COMPZ DRILL PULD P PJSM-Make up whipstock retrieving tools. 09:30 12:00 2.50 0 5,604 COMPZ DRILL TRIP P RIH to 5604' P/U 125k S/O 85k. 12:00 12:15 0.25 5,604 5,604 COMPZ DRILL OTHR P Latched whipstock on second try ulled 60k over strin wt. 12:15 12:30 0.25 5,604 5,573 COMPZ DRILL PULD P Lay down single. 12:30 13:00 0.50 5,573 5,573 COMPZ DRILL CIRC P CBU @ 86 spm 1800 psi No gas. 13:00 13:30 0.50 5,573 5,573 COMPZ DRILL CIRC P Monitorwell-static-pump dry job. 13:30 16:00 2.50 5,573 0 COMPZ DRILL TRIP P POH w! whipstock. 16:00 17:45 1.75 0 0 COMPZ DRILL PULD P Lay down BHA & whipstock ramp assembl . 17:45 18:30 0.75 0 0 COMPZ DRILL OTHR P Clear & clean rig floor. 18:30 19:00 0.50 0 220 COMPZ CASIN( RURD P P/U hook hanger tools from bottom of slide. 19:00 20:00 1.00 220 220 COMPZ CASIN( RURD P Rig up csg. tools. 20:00 20:30 0.50 220 220 COMPZ CASIN( SFTY P PJSM=on making up & running hook han er assembl . ~. ~~.---De~ ~~ ®~-~---° ~~ 2 oaf Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 07/25/2006 20:30 21:00 0.50 220 220 COMPZ RIGMN SVRG P Service top drive. 21:00 23:15 2.25 220 220 COMPZ CASIN( RURD P Make up hook hanger assembly slimhole MWD, space out tbg. for inner strin . 23:15 00:00 0.75 220 220 COMPZ CASIN( RURD P Lay down csg. tools, clear & clean rig floor. 07/26/2006 00:00 03:45 3.75 220 5,670 COMPZ CASIN( RUNL P Shallow test MWD-RIH to 5840'-Tag up in mother bore-pull up to 5670'. Rotate 3.5 turns to right-go thru window-orient 6 de .left. 03:45 04:45 1.00 5,670 5,694 COMPZ CASIN( RUNL P Hook window-unhook turn 180 deg. go past-pull up-rehook set down 35k twice-hook set on depth @ 5711'-top of hook 5694'. 04:45 05:30 0.75 5,694 5,694 COMPZ CASIN( CIRC P Drop ball-pump @ 2 bpm on seat @ 560 strokes-pressure up 2650 psi inflate ECP-release from hook-pressure to 4300 psi could not shear um out sub. 05:30 08:30 3.00 5,694 0 COMPZ DRILL TRIP P POH to 5672' monitor well pump pill & POH. 08:30 10:30 2.00 0 0 COMPZ CASIN( RURD P Rig down double stack tongs lay down hook running tool 3 jts. 2 7/8" wash i e & slim hole MWD. 10:30 11:30 1.00 0 0 COMPZ CASIN( RURD P Rig down tongs-clear & clean rig floor. 11:30 12:00 0.50 0 0 COMPZ CASIN( RURD P Rig up csg. equipment. 12:00 12:30 0.50 0 0 COMPZ CASIN( SFTY P PJSM=Hazard assesment on make up & runnin LEM. 12:30 15:30 3.00 0 5,653 COMPZ CASIN< RNCS P RIH w/ LEM on 4" DP to 5653'. 15:30 16:45 1.25 5,653 5,653 COMPZ CASIN< OTHR P Slid LEM into sealbore assembly, Latched up, unlatched then relatched, saw visual on wt. indicator, dropped ball & pumped down @ 36 spm 430 psi ball seat @ 460 strokes, pressured up to 2000 psi, saw shear, pump to 4000 si for 1 minute. 16:45 17:00 0.25 5,653 5,653 COMPZ CASIN( OTHR P Test ZXP packer @ 1000 psi for 10 minutes on chart. 17:00 17:45 0.75 5,653 5,653 COMPZ CASIN( CIRC P CBU @ 51 spm 770 psi. 17:45 18:00 0.25 5,653 5,653 COMPZ CASIN( RURD P Rig down test equipment. 18:00 18:30 0.50 5,653 5,653 COMPZ CASIN( CIRC P Pump dry job, blow down top drive & kill line. 18:30 20:45 2.25 5,653 0 COMPZ CASIN( OTHR P Monitor well-POH. 20:45 21:00 0.25 0 0 COMPZ CASIN( OTHR P Clean rig floor. & pull wear bushing. 21:00 21:45 0.75 0 0 COMPZ CASIN( RURD P Rig up csg. tools. 21:45 22:15 0.50 0 0 COMPZ CASIN( SFTY P PJSM on running tbg. w/ Baker re =Co. re & crew. ...~.,. ~'~ 3 Time Los ~ - 'Date From To Dur th E. De th Phase Code Subcode T OM 07/26/2006 22:15 00:00 1.75 0 660 COMPZ CASIN( OTHR P Running completion tbg. & accesaries. 07/27/2006 00:00 03:45 3.75 660 5,646 COMPZ RPCOti PULD P Continue to RIH w/ 4.5" 12.6# IBTM tbg. ran total of 180 jts. P/U 75k S/O 60k. 03:45 05:00 1.25 5,646 5,646 COMPZ RPCOh CIRC P Rig up circ. head Circ. 3 B/U @ 210 spm 810 gpm 1800 psi circ. till shakers clean ri down circ. head. 05:00 06:00 1.00 5,646 5,674 COMPZ RPCOh HOSO P RIH to 5674' tagged seal locator, pull u & s ace out w/ 5.80 u . 06:00 06:30 0.50 5,674 5,674 COMPZ RPCOh HOSO P Make up tbg. hanger & land tbg. P/U 75k S/O 60k. 06:30 07:30 1.00 5,674 5,674 COMPZ RPCOti DHEQ P RILDS-test tbg. hanger seals 5000 psi test10 mins. OK. 07:30 08:45 1.25 COMPZ RPCOh NUND P PJSM=Nipple down BOPE. 08:45 11:30 2.75 COMPZ RPCOh NUND P PJSM- nipple up tree-test void to 5000 si test tree & accuator 5000 si OK. 11:30 12:00 0.50 COMPZ RPCOCv OTHR P Rig up cellar for displacement. Rig up to la down DP from derrick. 12:00 12:15 0.25 COMPZ RPCOh SFTY P PJSM= hazard assesment on laying down drill i e. 12:15 13:15 1.00 COMPZ RPCOh PULD P Lay down 16 stands 4" drill pipe. 13:15 13:30 0.25 COMPZ RPCOh SFTY P PJSM=on Freeze protect. 13:30 15:30 2.00 COMPZ RPCOti FRZP P Freeze protect tbg. & annulus w/ 255 bbls. diesel 5 b m. 15:30 16:15 0.75 COMPZ RPCOCv PULD P Lay down 7 stands 4" drill pipe. 16:15 16:45 0.50 COMPZ RPCOh OTHR P Pick up BPV & set same w/ Vetco Gra . 16:45 21:00 4.25 COMPZ RPCOh PULD P Lay down the rest of slick pipe 82 stands. 21:00 00:00 3.00 COMPZ RPCOh PULD P Lay down 15 stands push pipe-7 stands hwdp-5 stands super slider i e. 07/28/2006 00:00 02:45 2.75 COMPZ RPCOh PULD P Continue laying down 4" DP from derrick-inspecting hard bands, removing supersliders from the ones that need new hard bands. 02:45 04:00 1.25 COMPZ RPCOCv OTHR P Clear & clean rig floor & cellar. (Release rig from 1J-156 to Rig Maintenance 7-28-2006 0400. m _~~ ~ _® ~ ~r~~ ~2 ~f ~Z Halliburton Compan~ Survey Report ('~unpaana: Fi~lil: ConocoPh=hips Alaska Inr_ Kuparuk River Unit 1)alc: 2/9/2006 7in~c: 09-09:55 I'ac: Cu-urdinatclA'I:) Itefcrcncc: Well: 1J-156, True North ~ilc: Kuparuk 1J Pad ~"r rtic~l 0111)) Kcfcrcncc: 1J-156- 109.0 \~cll: 1J-156 Jc ctiun(~S)Hcf crcnec: UJeIl0.00N.0- ODE130OOAzi) l~cllpaih: 1J-156 ~u nc~ Csleul;iii un 1lciho~l: Minimum Curv ature 11 h: Gracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 J-156 Slot Name: Well Position: +N/-S -13.52 ft Northing: 5945905.02 ft ~ Latitude: 70 15 46.125 N +E/-W -140.85 ft Easting : 558649.22 ft ~ Longitude: 149 31 33.105 W Position Un certainty: 0.00 ft Wellpath: 1J-156 Drilled From: Well Ref. Point 500292331100 Tie-on Depth: 28.00 ft Current Da tum: 1 J-156: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/28/2006 Declination: 24.04 deg Field Strength: 57565 nT Mag Dip Angle: 80.78 deg Vertical Sec tion: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 4/3/2006 Validated: No Ve rsion: 3 Actual From To Survey Toolcode Tool Name ft ft 50.00 539.00 1J-156 gyro (50.00-539.00) CB-GYRO-SS Camera based gyro single shot 628.39 8233.13 1J-156 (628.39-8233.13) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~II1 Intl liini I~VD tics 7 ~ ll V'~S 1 '~~' __ _ - ~Li~~A - ~la~l: ~lu~il ft deg deg ft ff ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945905.02 558649.22 TIE LINE 50.00 0.12 309.10 50.00 -59.00 0.01 -0.02 5945905.03 558649.20 CB-GYRO-SS 100.00 0.33 302.21 100.00 -9.00 0.12 -0.18 5945905.14 558649.04 CB-GYRO-SS 170.00 0.16 227.52 170.00 61.00 0.17 -0.42 5945905.18 558648.80 CB-GYRO-SS 261.00 0.84 274.09 261.00 152.00 0.13 -1.18 5945905.14 . 558648.04 CB-GYRO-SS 357.00 3.64 283.48 356.91 247.91 0.89 -4.85 5945905.87 558644.37 CB-GYRO-SS 446.00 7.52 285.11 445.47 336.47 3.07 -13.22 5945907.98 558635.98 CB-GYRO-SS 539.00 9.29 284.65 537.47 428.47 6.55 -26.36 5945911.36 558622.81 CB-GYRO-SS 628.39 10.78 282.16 625.49 516.49 10.14 -41.51 5945914.83 558607.63 MWD+IFR-AK-CAZ-SC 661.48 12.02 281.08 657.93 548.93 11.45 -47.92 5945916.10 558601.22 MWD+IFR-AK-CAZ-SC 697.90 13.22 279.83 693.47 584.47 12.89 -55.75 5945917.47 558593.38 MWD+IFR-AK-CAZ-SC 764.19 15.65 278.50 757.66 648.66 15.51 -72.06 5945919.96 558577.05 MWD+IFR-AK-CAZ-SC 856.58 15.78 279.44 846.60 737.60 19.41 -96.78 5945923.67 558552.30 MWD+IFR-AK-CAZ-SC 948.01 18.55 280.46 933.95 824.95 24.09 -123.35 5945928.15 558525.70 MWD+IFR-AK-CAZ-SC 1040.41 22.41 279.81 1020.49 911.49 29.76 -155.17 5945933.57 558493.84 MWD+IFR-AK-CAZ-SC 1133.37 25.84 279.39 1105.32 996.32 36.09 -192.63 5945939.60 558456.34 MWD+IFR-AK-CAZ-SC 1225.55 28.82 279.19 1187.20 1078.20 42.91 -234.39 5945946.10 558414.53 MWD+IFR-AK-CAZ-SC 1320.60 32.24 280.08 1269.06 1160.06 51.01 -281.98 5945953.83 558366.88 MWD+IFR-AK-CAZ-SC 1413.40 34.96 281.94 1346.35 1237.35 60.85 -332.37 5945963.27 558316.41 MWD+IFR-AK-CAZ-SC 1506.74 35.50 281.10 1422.59 1313.59 71.60 -385.13 5945973.61 558263.58 MWD+IFR-AK-CAZ-SC 1598.95 36.98 280.44 1496.96 1387.96 81.78 -438.68 .5945983.37 558209.95 MWD+IFR-AK-CAZ-SC 1692.74 39.87 279.40 1570.43 1461.43 91.80 -496.10 5945992.95 558152.47 MWD+IFR-AK-CAZ-SC 1782.84 46.17 278.46 1636.28 1527.28 101.31 -556.80 5946001.98 558091.71 MWD+IFR-AK-CAZ-SC 1875.42 48.72 278.17 1698.88 1589.88 111.17 -624.27 5946011.31 558024.16 MWD+IFR-AK-CAZ-SC 1967.60 52.01 275.99 1757.68 1648.68 119.88 -694.71 5946019.48 557953.67 MWD+IFR-AK-CAZ-SC 2060.57 58.03 272.32 1810.97 1701.97 125.31 -770.63 5946024.31 557877.71 MWD+IFR-AK-CAZ-SC 2154.73 58.56 270.78 1860.45 1751.45 127.47 -850.71 5946025.85 557797.63 MWD+IFR-AK-CAZ-SC 2242.55 60.83 269.43 1904.77 1795.77 127.60 -926.52 5946025.39 557721.83 MWD+IFR-AK-CAZ-SC 2335.91 60.92 269.25 1950.21 1841.21 126.66 -1008.07 5946023.82 557640.29 MWD+IFR-AK-CAZ-SC ;~ Halliburton Compan~ Survey Report (~~uupan~: ConocoPhillipsAlaskalnc Daa~: Ski-006 Time: 09:09'55 P:~r: 2 Field: Kuparuk River Unit Cu-~u~Iinatcl~Ll Kcli~rcncc: WeIL 1J-156. True North tiitc: Kuparuk 1J Pad \crtic,il f~llllj kcfcrcncc: 1J-150 109.0 \\ ~~II: 1J-156 tiectiun (\Sl ItcR~rcncc Well i0-OON,O-OOE.100 00Azi) \1ellpath: 1J-156 tiin~c~ (alculatiun ~Icthnd: Minimwn Curvature 11h: Oracle Jw~c~ \IU Incl \iim ll'1) `~~ll I) \ :ti I; \1 \lap\ \lal~l: I~iul ft deg deg ft ft ft ft ft ft 2429.73 60.92 270.59 1995.81 1886.81 126.55 -1090.06 5946023.06 557558.31 MWD+IFR-AK-CAZ-SC 2523.25 61.26 268.34 2041.02 1932.02 125.78 -1171.91 5946021.66 557476.48 MWD+IFR-AK-CAZ-SC 2616.59 57.90 268.87 2088.28 1979.28 123.82 -1252.37 5946019.07 557396.05 MWD+IFR-AK-CAZ-SC 2709.57 58.96 268.53 2136.96 2027.96 122.02 -1331.56 5946016.65 557316.87 MWD+IFR-AK-CAZ-SC 2729.48 59.49 268.15 2147.14 2038.14 121.52 -1348.66 5946016.02 557299.78 MWD+IFR-AK-CAZ-SC 2826.57 60.03 267.98 2196:04. 2087.04 118.69 -1432.49 5946012.54 557215.98 MWD+IFR-AK-CAZ-SC 2920.36 58.92 266.59 2243.68 2134.68 114.87 -1513.19 5946008.09 557135.33 MWD+IFR-AK-CAZ-SC 3012.90 58.01 264.09 2292.08 2183.08 108.47 -1591.79 5946001.08 557056.78 MWD+IFR-AK-CAZ-SC 3108.25 57.70 263.40 2342.82 2233.82 99.67 -1672.04 5945991.66 556976.61 MWD+IFR-AK-CAZ-SC 3202.47 59.79 259.98 2391.71 2282.71 88.01 -1751.72 5945979.38 556897.04 MWD+IFR-AK-CAZ-SC 3295.75 61.28 254.21 2437.62 2328.62 69.85 -1830.82 5945960.61 556818.08 MWD+IFR-AK-CAZ-SC 3389.35 61.96 248.08 2482.14 2373.14 43.25 -1908.70 5945933.39 556740.43 MWD+IFR-AK-CAZ-SC 3482.06 60.16 242.90 2527.03 2418.03 9.63 -1982.49 5945899.21 556666.90 MWD+IFR-AK-CAZ-SC 3575.84 59.32 237.52 2574.31 2465.31 -30.57 -2052.76 5945858.46 556596.96 MWD+IFR-AK-CAZ-SC 3669.53 59.15 236.82 2622.23 2513.23 -74.22 -2120.40 5945814.30 556529.66 MWD+IFR-AK-CAZ-SC 3762.54 59.35 236.61 2669.79 2560.79 -118.08 -2187.22 5945769.91 556463.19 MWD+IFR-AK-CAZ-SC 3856.53 59.81 237.44 2717.38 2608.38 -162.20 -2255.22 5945725.28 556395.55 MWD+IFR-AK-CAZ-SC 3949.79 62.02 236.39 2762.71 2653.71 -206.69 -2323.49 5945680.26 556327.63 MWD+IFR-AK-CAZ-SC 4041.96 62.70 235.18 2805.47 2696.47 -252.60 -2391.01 5945633.83 556260.48 MWD+IFR-AK-CAZ-SC 4135.29 62.94. 233.80 2848.11 2739.11 -300.83 -2458.59 5945585.08 556193.28 MWD+IFR-AK-CAZ-SC 4228.84 63.84 233.61 2890.01 2781.01 -350.34 -2526.00 5945535.05 556126.27 MWD+IFR-AK-CAZ-SC 4324.27 63.22 228.72 2932.57 2823.57 -403.87 -2592.52 5945481.00 556060.17 MWD+IFR-AK-CAZ-SC 441.5.66 61.95 227.40 2974.64 2865.64 -458.09 -2652.87 5945426.33 556000,25 MWD+IFR-AK-CAZ-SC 4511.02 62.68 223.46 3018.96 2909.96 -517.34 -2713.00 5945366.62 555940.59 MWD+IFR-AK-CAZ-SC 4604.16 61.72 221.00 3062.41 2953.41 -578.33 -2768.38 5945305.20 555885.70 MWD+IFR-AK-CAZ-SC 4695.44 62.82 217.23 3104.89 2995.89 -641.01 -2819.32 5945242.13 555835.25 MWD+IFR-AK-CAZ-SC 4789.29 65.39 211.95 3145.90 3036.90 -710.50 -2867.19 5945172.28 555787,93 MWD+IFR-AK-CAZ-SC 4882.76 66.00 206.67 3184.39 3075:39 -784.75 -2908.86 5945097.71 555746.84 MWD+IFR-AK-CAZ-SC 4977.56 66.41 201.68 3222.66 3113.66 -863.85 -2944.37 5945018.34 555711,95 MWD+IFR-AK-CAZ-SC 5071.42 68.37 197.34 3258.76 3149.76 -945.50 -2973.27 5944936.48 555683.69 MWD+IFR-AK-CAZ-SC 5163.66 71.51 194.39 3290.40 3181.40 -1028.83 -2996.93 5944852.98 555660,68 MWD+IFR-AK-CAZ-SC 5257.97 72.05 190.73. 3319.90 3210.90 -1116.25 -3016.40 5944765.42 555641.89 MWD+IFR-AK-CAZ-SC 5351.05 75.87 186.20 3345.62 3236.62 -1204.69 -3029.53 5944676.88 555629.46 MWD+IFR-AK-CAZ-SC 5444.97 76.47 180.99 3368.09 3259.09 -1295.68 -3035.24 5944585.87 555624.45 MWD+IFR-AK-CAZ-SC 5538.34 77.43 178.91 3389.17 3280.17 -1386.63 -3035.16 5944494.93 555625.25 MWD+IFR-AK-CAZ-SC 5631.47 78.39 178.69 3408.68 3299.68 -1477.67 -3033.25 5944403.91 555627.86 MWD+IFR-AK-CAZ-SC 5722.81 78.34 178.91 3427.10 3318.10 -1567.12 -3031.38 5944314.49 555630.43 MWD+IFR-AK-CAZ-SC 5815.21 78.12 177.99 3445.95 3336.95 -1657.54 -3028.93 5944224.10 555633.58 MWD+IFR-AK-CAZ-SC 5909.06 80.59 179.04 3463.28 3354.28 -1749.73 -3026.54 5944131.93 555636.69 MWD+IFR-AK-CAZ-SC 6002.04 80.60 179.31 3478.48 3369.48 -1841.46 -3025.22 5944040.24 555638.72 MWD+IFR-AK-CAZ-SC 6097.15 80.55 179.09 3494.05 3385.05 -1935.27 -3023.91 5943946.44 555640.76 MWD+IFR-AK-CAZ-SC 6189.33 79.05 179.00 3510.38 3401.38 -2025.98 -3022.40 5943855.76 555642.98 MWD+IFR-AK-CAZ-SC 6283.41 80.13 180.91 3527.38 3418.38 -2118.51 -3022.33 5943763.24 555643.77 MWD+IFR-AK-CAZ-SC 6378.64 82.97 180.60 3541.37 3432.37 -2212.68 -3023.57 5943669.07 555643.26 MWD+IFR-AK-CAZ-SC 6470.01 82.65 181.84 3552.81 3443.81 -2303.31 -3025.50 5943578.43 555642.04 MWD+IFR-AK-CAZ-SC 6566.76 81.04 180.40 3566.53 3457.53 -2399.06 -3027.38 5943482.68 555640.91 MWD+IFR-AK-CAZ-SC 6657.02 79.64 180.73 3581.68 3472.68 -2488.03 -3028.25 5943393.72 555640.73 MWD+IFR-AK-CAZ-SC 6751.77 79.52 181.25 3598.81 3489.81 -2581.21 -3029.86 5943300.54 555639.84 MWD+IFR-AK-CAZ-SC 6845.86 81.59 180.10 3614.25 3505.25 -2674.01 -3030.95 5943207.74 555639.48 MWD+IFR-AK-CAZ-SC 6927.74 85.91 178.11 3623.16 3514.16 -2755.37 -3029.68 5943126.40 555641.39 MWD+IFR-AK-CAZ-SC 7028.44 86.49 177.09 3629.84 3520.84 -2855.76 -3025.47 5943026.06 555646.38 MWD+IFR-AK-CAZ-SC 7059.27 86.28 177.24 3631.78 3522.78 -2886.49 -3023.95 5942995.35 555648.14 MWD+IFR-AK-CAZ-SC Halliburton Compan~ Survey Report ('nmpam: ConucoPhillips Alaska Inc. Ficl~l: Kuparuk P.iver Unit ~itc: Kuparuk 1J Pad ~1cll: 1 J-1 56 ~~'cllpsth: 1J-156 Surcc~ 11a1c: 3i 9'2006 jinn: 090955 I'a<~c: 3 Cu-i~rdinatclAFl Rclcrcucr. Well: 1J-156. True North ~ crtico-il (III)) ILefcrcucc: 1J-156. 109.0 Scciiun ~~~) Ilcf~rcnrc Well (0 OON,O OOE180 OOAzi) ~ur~c~ (alculnlinu >icU~oil: Minimum Curvature Uh: Orade )lU Incl ~cini 7I~1) ~cslll) A,~ Li~1 11a~~A ft deq deg ft ft ft ft ft 7120.08 85.17 178.24 3636.32 3527.32 -2947.08 -3021.55 5942934.78 7211.48 82.34 177:80 3646.26 3537.26 -3037.87 -3018.42 5942844.02 7300.64 83.45 176.40 3657.29 3548.29 -3126.23 -3013.94 5942755.71 7391.85 87.76 179.04 3664.27 3555.27 -3217.07 -3010.33 5942664.91 7481.33 90.81 180.13 3665.39 3556.39 -3306.53 -3009.68 5942575.47 7573.99 92.17 179.89 3662.98 3553.98 -3399.16 -3009.70 5942482.85 7664.24 89.60 181.43 3661.59 3552.59 -3489.38 -3010.74 5942392.63 7754.23 94.04 181.93 3658.73 3549.73 -3579.26 -3013.37 5942302.74 7845.11 93.44 183.14 3652.80 3543.80 -3669.86 -3017.38 5942212.12 7936.53 92.86 184.35 3647.78 3538.78 -3760.94 -3023.35 5942121.00 8027.36 94.07 183:21 3642.29 3533.29 -3851.41 -3029.32 5942030.51 8119.52 93.12 180.62 3636.51 3527.51 -3943.33 -3032.40 5941938.57 8208.58 91.89 179.05 3632.62 3523.62 -4032.30 -3032.14 5941849.62 8233.13 91.46 178.18 3631.90 3522.90 -4056.83 -3031.55 5941825.09 8281.00 91.46 178.18 3630.68 3521.68 -4104.66 -3030.03 5941777.28 ~la~~l_ lnul ft 555651.00 MWD+IFR-AK-CAZ-SC 555654.84 MWD+IFR-AK-CAZ-SC 555660.01 MWD+IFR-AK-CAZ-SC 555664.33 MWD+IFR-AK-CAZ-SC 555665.67 MWD+IFR-AK-CAZ-SC 555666.38 MWD+IFR-AK-CAZ-SC 555666.04 MWD+IFR-AK-CAZ-SC 555664.10 MWD+IFR-AK-CAZ-SC 555660.80 MWD+IFR-AK-CAZ-SC 555655.55 MWD+IFR-AK-CAZ-SC 555650.28 MWD+IFR-AK-CAZ-SC 555647.92 MWD+IFR-AK-CAZ-SC 555648.87 MWD+IFR-AK-CAZ-SC 555649.65 MWD+IFR-AK-CAZ-SC 555651.55 'PROJECTED to TD • • WELL LOG TRANSMITTAL To: State of Alaska August 11, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-156, L1, L1 PB1 & L2, AK-MW-4467716 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23311-00, 60, 70, 61. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETiJRNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: (~, Signed: `~~~ ~~~~~ AUG 2 2 200E q C)il & Gas Cons. Commission Anchorage ~ c~Olu -O(o`~-~ c70~.' OC~~i add -06~ '~'/yp~~ 07/24/06 ~J Se~~er Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ - ~~~ Log Description NO. 3887 Company: Alaska Oil ~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Date BL Kuparuk Color CD 1E-102 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE 05/20/06 1 1 E-105L1 11213766 INJECTION PROFILE 06/20/06 1 16-18 NIA PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE WlDEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07!10/06 1 2K-O6 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1H-04 11320991 INJECTION PROFILE 07103/06 1 1D-10'1 NIA INJECTION PROFILE 06/27/06 1 2Z-13 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILEIDEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28J06 1 iJ-101 40012836 MD & TVD VISION RESISTIVITY 12120/05 2 1 .7 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. n LJ ~ '~ ~ - ALASSA OIL A1QD GAS CO1~tSERQATIOIQ COl-Il~iISSIOIQ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 CJ FRANK H. MURKOWSK/, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-156 ConocoPhillips Alaska, Inc. Permit No: 206-067 Surface Location: 2094' FSL, 2560' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 3268' FSL, 290' FEL, SEC. 3, T l ON, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, DATED this~'day of June, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ConocoPhillips Alaska ~: Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 12, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1J-156, iJ-156 Li, iJ-156 L2 Dear Commissioners: r 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 1]- 156, and the lateral bores of the well will be designated 1J-156L1 and iJ-156L2. 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-156 is July 13, 2006. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, ~. \ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~, j PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill 0 Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^~ - Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 - 11. Well Name and Number: 1J-156 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: ' MD: 8317' TVD: 3637' J 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2094' FSL, 2560' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation:,l~` ~(,(~ ADL 25663 zS~G i ~, G D West Sak Oil Pool Top of Productive Horizon: 4719' FSL, 307' FEL, Sec. 3, T10N, R10E, UM 8. Land Use Permit: ALK 472 13. Approximate Spud Date: 7/13/2006 Total Depth: 3268' FSL, 290' FEL, Sec. 3, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to ~~ S ,~~.~ Nearest Property: ~jfF2 miles to KRU 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558649 " y- 5945905 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1J-152 , 1246' @ 9225' 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: g2° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1637 psig ' Surface: 1237 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2768' 28' 28' 2791' ' 2168' ~ 510 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7.625" 29.7# L-80 BTCM 6835' 28' 28' 6863' . 3628' 400 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 2265' 6052' 3500' 8317' . 3637' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee O BOP Sketch Drilling ProgramQ Time v. Depth Plot Shallow Hazard Analysis 0 Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program 0 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 Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature t ` Phone ZG S-6 $ 30 Date S ~t 'LIOG P h n All r k Commission Use Only Permit to Drill Number: ~~ ~ ~~ API NumTber:q 50- ~,lZ / - ~ 3 3 /(~ ~~ Permit Approval Date: • ~ . ~ See cover letter for other requirements Conditions of approval : If box is checked, we ay not be used to explore for, test, or produce Coalbed me ane, shy ales, or gas contained in shales: ~` ~~~Si-Cs-,S ~G,~t~ Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No nthPr ~~~^~ ~~~~C,\ ~`~~f~© H2S measures: Yes [,y it tional svy req'd: Yes [~ No ^ l~`~-tt"~+r=~,~C'E3 ~.cuY~-'ti®r-S`T~~yecp~ ~''lasl,© APPROVED BY THE COMMISSION DATE: (% ~?r- ~ D ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~, ! Submit in Duplicate ~Jl~~~b~Gl~ t ~tion for Permit to Drill, Well 1 J-156 Revision No.O Saved: 12-May-06 Permit It -West Sak Well #1J-156 Application for Permit to Drill Document well Vo1ue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 not done 1J-156 PERMIT IT Page 1 of 8 Printed: 12-May-06 C J ~tion for Permit to Drill, Well 1 J-156 Revision No.O Saved: 12-May-06 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 Attachment 5 1/4 Mile Radius Effect for Injector ......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (1) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-156. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,094' FSL 2,560' FEL, Section 35, T11N R10E - ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL . Northings: 5,945,905 Eastings: 558,649 Pad Elevation 81.0' AMSL Location at Top of , Productive Interval 4,719' FSL, 307' FEL, Section 3, T10N, R10E West Sak "A2" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 6 863 Northings: 5,943,227 Eastings: 555,645 Total Vertical De th, RKB: 3,628 Total Vertical De th, SS: 3,519 Location at Total De th 3,268' FSL, 290' FEL, Section 3, T10N, R10E - ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 8,317 Northings: 5,941,777 Eastings: 555,675 Total Vertical De th, RKB: 3,637 Total Vertical De th SS: 3 528 not done 1J-156 PERMIT IT Page 2 of 8 Printed: 12-May-06 ORIGINAL and (D) other information required by 20 AAC 25.050(b); ~tion for Permit to Drill, Well 1J-156 Revision No.O Saved: 12-May-06 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (i) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan iJ-156 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-156. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled ~~Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,237 psi, calculated thusly: MPSP = (3,637 ft TVD)(0.45 - 0.11 psi/ft) = 1,237 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: iJ-156 Drilling Hazards Summary. not done 1J-156 PERMIT IT Page 3 of 8 Printed: 12-May-06 ~~~l~~L • ~tion for Permit to Drill, Well 1J-156 Revision No.O Saved: 12-May-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); iJ-156 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program /~`\ o Attach ~: Ce um 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 a 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,791 28 / 28 2,791 /2,168 510 sx ASLite Lead, 180 sx DeepCRETE Tail drift Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 6 863 28 / 28 6,863 / 3,628 3,650' MD / 2,592' TVD. , Cemented w/ 400 sx DeepCRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 2,265 6,052 / 3,500 8,317 / 3,637 Slotted- no cement Slotted Lateral (1J-156) - - 1 - ~ ~ ~ ~ 68 otted- slotted Lateral (1J-156 L1) 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 6,971 5,625 / 3,404 12,596 / 3,296 Slotted- no cement slotted Lateral (1J-156 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under ZO AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-156. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: not done 1J-156 PERMIT IT Page 4 of 8 Printed: 12-May-06 • Surface Hole Mud Program (extended bentonite) ~tion for Permit to Drill, Well 1 J-156 Revision No.0 Saved: 12-May-06 S ud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 9.5 9.6 Funnel viscosity 150 250 200 300 seconds Yie-d Point 50 70 30 50 (cP) Plastic Viscostiy 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 API Filtrate NC 8.0 5.0 7.0 (cc / 30 min)) *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI VersaPro Mineral Oil Base) AIB/D sand laterals 10-3/4" Cs Shoe to 7-5/8" Cs Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity 45 - 60 (seconds) Plastic Viscostiy 12 - 18 (Ib/100 sfJ Yield Point 26 - 35 (cP) API Filtrate 4 - 6 (cc / 30 min)) Chlorides (mg/I) <500 pH 9.0 - 9.5 MBT <20.0 Value Density ( ) 8.8 Plastic Viscostiy 15 - 25 Ib/100 sf) Yield Point 18 - 28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 70 / 30 Electrical >600 Stabilit Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by ZO AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i0) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. not done 1J-156 PERMIT IT Page 5 of 8 Printed: 12-May-06 .;~iIGINAL • ~tion for Permit to Drill, Well 1J-156 Revision No.O Saved: 12-May-06 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i 1) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i2) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,791' MD / 2,168' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 6,863' MD / 3,628' TVD, the prognosis top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 3,651' MD / 2,593' 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. li. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (Expected ECD's in 6-3/4" lateral modeled to be less than 12.5 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 8,317' MD / 3,637' TVD as per directional plan. not done 1J-156 PERMIT /T Page 6 of 8 Printed: 12-May-06 ORIGINAL ~tion for Permit to Drill, Well 1 J-156 Revision No.O Saved: 12-May-06 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. PU and run 4-1/2" slotted liner. "~'~~~ 'iv~~~- 17. Land liner, set liner hanger @ +/- 6,052' MD / 3,500' ND. POOH. Note: Remaining operations are covered under the 1J-156L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,952' MD / 3,476' TVD, the top of the B sand. 19. Mill 6-3/4" window. POOH. 20. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at +/- 12,994' MD / 3,368' TVD, as per directional plan. 22. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 1J-156L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,625' MD / 3,404' TVD, the top of the D sand. 29. Mill 6-3/4" window. POOH. 30. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at +/- 12,596' MD / 3,296' TVD, as per directional plan. 32. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4-1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool. POOH. 37. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 38. POOH, laying down drill pipe as required. 39. PU injection completion and RIH to depth. Land tubing. Set BPV. 40. Nipple down BOPE, nipple up tree and test. Pull BPV. 41. Freeze protect well with diesel. not done 1J-156 PERMIT IT Page 7 of 8 Printed: 12-May-06 ~~~~~ fitt • 42. Set BPV and move rig off. ~tion for Permit to Drill, Well 1 J-156 Revision No.O Saved: 12-May-06 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic not done 1J-156 PERMIT IT Page 8 of 8 Printed: 12-May-06 ORIGINAL KE: 1J-156 Bond Log • • Subject: RE: l.(-1 ~6 Bond Log From: "Greener, Mike R." <Mike.R.Greener~u~conocophillips.com=~ Date: Thu, ?5 May ~Of)G 16:t~7:~3 -08OU "To: Thomas Maundet~ <=tom maunder(i%~tdmi~l.state.ak.u5=~ Sorry about that. Forgot to put it in. We will run a conventional USIT log after we finish drilling the first lateral but before we run the liner on the 1J-156 mother bore. -----Original Message----- From: Thomas Maunder [mailto:tom maunder~adr:.in.state.ak.us Sent: Thursday, May 25, 2006 3:49 PM To: Greener, Mike R. Subject: 1J-156 Bond Log Hi Mike, I left you a message. Where in the well trio are you planning for a bond log? I have looked over the procedure and have not found it. Will you use the new sonic tool or conventional? Thanks, Tom Maunder, PE AOGCC 1 of 1 5/25/2006 4:15 PM ConocoPhillip5 ~~~ ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-156 -Slot 1J-156 1 J-156 Plan: 1J-156 (wp05) Proposal Report 14 April, 2006 • ~" ~. ~peirry Drilling Sieirvices ~ ~~~yL c E ~ ~ oa ~°Uf~Q pUfOQQQ d tahON EO M>>> YYYYYY M N N N H VI N V1N°nV timFM-YF->j7Y~i~~~i ~S~ J ~MO)~tp it N'-tnOGOMNM V N ~' Q t0 t0 Of 10 ~OVr~ MQVM (A CON ~.. d 00 N In r ~ V> V N~ N N M M E. M.. NOIOONNOMN MNOO In ~O J OGO~~ W p 10 f~Ml~e-~ f~Ot00001~ V a0 F ZN~r-v 1 ~L~a-NN<V V'1gN ~MtO tO tO W p pom~v O ~Om o r y.-IOMOlhi~O»~ Nh O0 V 0> (~ G~MI~ Z (n ~"' MNN NOODNOI V 1D 01f)s Z pp O~~p~ p~~000r~Of Of ~NMM ~aN f~ O D M O ~ N N N N M M M M M M M (n N 10 O] Q Q U ~ Q>OO,°o, °otO+f p I-- O O O r W L O O O O O O O O O O N O 0 0 m~nNO.i 00000000000000 <om douirieo<o~cedoiv~~d~.~ico NMM N~MtOM~01MO~f~~tON pN 100'-a000N~ V ONI[f f0 O F~' •'~N NM MMM MMMMM Z ~ N M a O ~ ~ ~ ~ ~ Z '- N M ~} ~O t0 1~ 00 0] f ~+ r a C ~~ ~a~;~o ~r`-~; Y Y r ~ r ~ ~ ~ ~ ~ ~ ~ 3a `oi YY_~~ ~ d7 C ~ ~ ~ ~ d n f °n ~ ~ N ~ C ~ N ~ ~ ~O O M ~ ~ N N G ~ A N ~ ~ ~ ~ C O ~ ~ A N M ~ f ry{y Q ~ C C m \ \ \ \ \ .O N d .~ ~ N m b N ~ .. pa`~ G ~ !'~ a U~ \ ~ \\ ~ 1~ \ \ \ \ C 0 \ p \ N ~ \ \ \ ~ ~ \ 0 ~ U \ G' tt \ C \ N \ ~ C \ C \ - \ m d \ O o \ f O \ p~ \ \ \ L" ~\ C \ \ ~ \ v \ e~ \ U \ @I - \ \ c V v . N O \\ \ ~qq O \ \ y \ \ m C ~ ~ \ N \ \ \ \ \ \ \ 0 N ~ ~ \\ \\ \\ \ \ M O y N \ \ \\ \\ \\ \ \ \\ ~ ~ \ \ \ \ \\ \ M ~ - - \ \ \ , _ _ f \ \ \ \ \ \ ~ o \ \ \ \ \ \ \ \ \ \ ~ ~ m \ \ \ \ \\ \ \ \ N r ~ \ ~ M \ \ \ \ \ \ 0 3 \ \ c ~ ~ \\\ \ \ \ \ \ \ \ \ ~ ~ \ U \\ \ \\ \ \\ \ .°O ~ \ \\ \ \ \ \ ~p+/ \ \ \ D y \\ \\ \ \ \\ \ 7 \ \ \ \ \ m ~ \\ \ \ \ \ \ \ o \ ` \ \ \ \ U \ \ \ \ \ \ \ \ \ \ \\ \ \ \ \ o \ \ \ \ \ \ \ \ ~ \ \ \ \ F- ~ \ \ \ \ \ \ \ M M \\ \\ \\ \ \\ \ U p` ~ \ \ \ \\ \ Qh, ff1 d ~ ~ \ \ \ \ ~Q° \ \ 0~ !9 1 ~ \ \ \ h D N >QNN T °%~ r V C ~ I `~~ I r91 I ~ Y ~ ~ ~\ ° \ Y \ o ° \ \ \ I I\ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ N \ O ~ ~ N O \ ° O M \,b I c e0 e\ b ~~ N ko I e\ I\ I N ~ I I I ~ m I ~ U rn a I LL ~ OI N ~_, A h A m ~ Y ~ o I N ~ I c I ~ I I I I I I I I I I I I~ I Y I I ~ I I f ~ III I G I :III I VIII I a ~ • O ~ ~ O IIIII I ~ ~ ^ ~ I II I I I N ~ i _ _ _ VIII I $, Q ~O VIII I I IIII I ~ J _ ~M7 ,~ u ~ VIII I IIIII I IIIII I IIIII I u r W ~ ~ +Q I O W IIIII I IIIII I VIII I VIII I ulll IIII I IIII I IIII I IIII I IIII I (~ v O ~ o ~ n O 1111 I IIII I IIII I IIII I IIII I IIII I f l l I I (IIII I IIIII I IIIII I N y ~ 0 r` O ~ O O O III I III I ~ `n ~ o ~ I III I I III I M ~ ~ I III I I III I ~ O I III I III M W I ~ N N III I 3 I J ' m I I I I I I a ~ O I I I I 1 I I I I .O / I' O C N j I I I I I I I I I // r / ^ ' a 3 Oo O I I I I , i l l I I // / ~ ~ ~ G O ~ p I I I I I / ~~ I t l I i // ~ 3 ~ I1 Ir/ ~ F G ~ i III ~ b ~ a 3 o c 0 0 0 I I I I I I I ~ ' N F ~ m ~ N V ~ N N ~ I II \ I '~, I I I 2" \I II I O M ~ ~ O C > ) ', I ~' N M I I C I ~ O / M I I I \ ~' ~ ' ~ y G o M 00 1 1 ~ ~ \ iD O ~ O M i I LZ ,'~ ~ I I Id -- I I I -------- _ _ _ _ - rn _ _ _ _ _ tO C o o I I I I I I _ ~ N I I I .~.. II II C a ~ O ~ O O O I I I I I I I I - - eQ ~ ~ ~ ~ N I I I I - - - _ I I I J IIII I`` -- -_ b 7 m O O ~ III I Intl I \ 111114 VIII I ~ N ~ ~ ~ ~ o o IIIII I I IIII I G _ ~ ~ IIIII I IIIII I I II11 l Y ~ m b o 111 1 1 l Nq 1111115 ' ~ ~ C ~ VIII II o IIIII A 1111 I I IIII I ~ m ~ 3 m ~ O w 0 ) / / m o / Ill ld I / // ~ M Q IIIII I/ ~ an ~ I,Irl,r,/ I ~ ____ _--- m IVVI~I, ~ _ - -' O ~ O °v O a O ~0n O ~ ~ OOOI) Sail 500 Continue Tum ~ 4.5/100ft , 3016ft MD, 2277ft N' Sail ~ 61°Inc 8 234°Aa : 3706ft MD, 2620ft - ' - - _ _ _ _ - - _ Continue Build/Tum ~ 4.5I100ft , 4340ft MD, 2927ft N Sail ~ 77°Inc & 179°Azi : 5525ft MD, 3382ft -1000 -1500 Build ~ 5°/100ft to 80°Inc - 5892ft MD, 3464ft N -2000 Sail ~ 80° Inc : 5952ft MD, 3476ft N Build ~ 5°/100ft to 86°Inc - 6743ft MD, 3613ft N Sail ~ 66°Inc :6863ft MD, 3628ft N f a 0 N -6000 0 0 o _ + BHL LID 8317ft MD, 3637f N L 1= O Z s 0 1J-156 DD Poly (wp05) DD Polygon Describes a corridor 100' wide with a 50'+/- allowance FJW from the aroposed wellbore. CASING DETAILS No TVD MD Name Size 1 80.00 80.00 20" 20 2 2168.00 2791.96 10 3/4" 10-3/4 3 3628.00 6863.44 7 5/8" 7-5/8 4 3637.30 8317.04 4 1 /2" 4-1 /2 mat-rait.~~~c~iv Sperry Drilling Services r„~ I ConocoPhillips Alaska 7pp, - - - - 1 J-156 T1 Dtop (wp05) 179° - Continue Build (ID 3.5/100ft , 702ft MD, 7008 N ~ KOP tiID 300ft MD, 3008 TVD - Build ~ 2.5°NO SHL~2094ftFSL&2560ftFEL-Sec~S~".'b:-R10 ~ 17s° 7 5/8" @ 6863ft MD, 3628ft TVD ___~__' ___________________Build~3.00/10pft,6883.45ftMD,3629.39RN Contlnue Geo-Steering In Upper A2 Sand. 7032ft MD. 3634ft N 1J-156 T2 (wp05) - - - - - 1 J-156 T3 (wp05) 79° 1J-156 T4 (wp05) 1J-156 T5 Toe (wp05) - 41/2" 1J-156 L2 (wp05) ~ 12596ft M -8500 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1 J-156 -sooo Wellbore: 1J-156 Plan: 1J-156 (wp05) ~ - - - - - - - - 1J-156 L1 (wp05) ~ 12995ft M -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 r1 I~ ~ .aA(est(s)/~as~(+).(1000 ft/in) B 270°Azi : 2166ft MD, 1864ft Continue Buildlrum ~ 4.5/100ft , 1702ft MD, 1575ft N ` Sail ~ 42° Inc : 1602ft MD, 1500ft N ~ _ N _ n _ H _ ~ _ T ~.zimuths to True N^ ih Magnetic North: 24.04° Magnetic Field Strength: 57564.2nT Dip Angle: 80.77° Date: 6/30/2006 Model: BGGM2005 0 500 1000 1500 2000 ~' • Halliburton Energy Services • lM-~Al.LEBIJpTClN ~Ot'1000~'11~~1S Planning Report -Geographic -~~~ Spen'y Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-156 -Slot 1 J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk iJ Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-156 Design: 1 J-156 (wp05) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1 J-156 -Slot 1 J-156 Well Position +N/-S 0.00 ft Northing: 5,945,905.10 ft Latitude: 70° 15' 46.125" N +E/-W 0.00 ft Easting: 558,649.10ft Longitude: 149° 31' 33.109" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1 J-156 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 6/30/2006 24.0422 80.7745 57,564 Design 1J-156 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ftl l°) 28.00 0.00 0.00 180.00 4/14/2006 9:43:58AM Page 2 of 9 COMPASS 2003.11 Build 50 OR!61NAL ` • ~ 1 •- ' Halliburton Energy Service s t~;a~.~aeui~~'t~N COPK)CO 11~ ~~ f~J S Planning Report -Geographic ~ ~ Sperry Drilling Serviiess Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-156 Design: 1 J-156 (wp05) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/_$ +E/-W Rate Rate Rate TFO lft) (°) (°) (ft) (ft) (ft) {°1100ft) (°/100ft) {°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.0000 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.0000 702.06 10.05 280.00 700.00 6.11 -34.64 2.50 2.50 0.00 280.0000 1,601.91 41.55 280.00 1,500.00 73.26 -415.48 3.50 3.50 0.00 0.0000 1,701.91 41.55 280.00 1,574.84 84.78 -480.80 0.00 0.00 0.00 0.0000 2,166.31 60.98 270.00 1,864.49 111.82 -839.49 4.50 4.18 -2.15 334.8056 3,016.31 60.98 270.00 2,276.84 111.82 -1,582.78 0.00 0.00 0.00 0.0000 3,705.80 60.98 234.38 2,619.73 -68.18 -2,143.06 4.50 0.00 -5.17 -98.8546 4,339.80 60.98 234.38 2,927.27 -391.07 -2,593.73 0.00 0.00 0.00 0.0000 5,525.44 77.00 179.30 3,381.50 -1,340.18 -3,040.87 4.50 1.35 -4.65 -84.7187 5,625.44 77.00 179.30 3,404.00 -1,437.61 -3,039.68 0.00 0.00 0.00 0.0000 5,892.44 77.00 179.30 3,464.06 -1,697.74 -3,036.50 0:00 0.00 0.00 0.0000 5,952.44 80.00 179.30 3,476.02 -1,756.53 -3,035.78 5.00 5.00 0.00 0.0000 6,743.44 80.00 179.30 3,613.38 -2,535.45 -3,026.27 0.00 0.00 0.00 0.0000 6,863.44 86.00 179.30 3,628.00 -2,654.50 -3,024.81 5.00 5.00 0.00 0.0000 6,883.44 86.00 179.30 3,629.39 -2,674.45 -3,024.57 0.00 0.00 0.00 0.0000 7,032.26 90.45 178.89 3,634.00 -2,823.14 -3,022.23 3.00 2.99 -0.27 -5.2214 7,097.08 90.45 178.89 3,633.50 -2,887.94 -3,020.97 0.00 0.00 0.00 0.0000 7,259.25 81.54 179.43 3,644.82 -3,049.53 -3,018.60 5.50 -5.49 0.33 176.5984 7,335.76 81.54 179.43 3,656.07 -3,125.21 -3,017.85 0.00 0.00 0.00 0.0000 7,549.33 92.22 179.30 3,667.67 -3,338.14 -3,015.48 5.00 5.00 -0.06 -0.6849 7,649.33 92.22 179.30 3,663.80 -3,438.06 -3,014.26 0.00 0.00 0.00 0.0000 7,658.29 92.40 179.30 3,663.44 -3,447.01 -3,014.15 2.00 2.00 -0.02 -0.5695 8,148.92 92.40 179.30 3,642.90 -3,937.17 -3,008.14 0.00 0.00 0.00 0.0000 8,211.01 91,80 179.45 3,640.63 -3,999.21 -3,007.47 1.00 -0.97 0.25 165.7080 8,317.05 91.80 179.45 3,637.30 -4,105.20 -3,006.45 0.00 0.00 0.00 0.0000 4/14/2006 9:43;58AM Page 3 of 9 COMPASS 2003.11 Build 50 ORIGINAL ` • • ~ - Halliburton Energy Service s Ha~~.teu>RTOnr C011000 ~1ht5 Planning Report -Geographic - -------~-~ Sperry Drilling Services. Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1J-156 Design: 1 J-156 (wp05) Planned Survey 1J-156 (wp05) MD Inclination Azimuth TVD SSTVD +N7-S Ift) (°l (°) Ift) ift) lft) 28.00 0.00 0.00 28.00 -81.00 0.00 SHL @ 2094ft FSL & 2 550ft FEL -Sec 35 - T11 N - R10E 80.00 0.00 0.00 80.00 -29.00 0.00 20" 100.00 0.00 0.00 100.00 -9.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 KOP @ 300ft MD, 300ft TVD -Build @ 2.5°/100ft , 400.00 2.50 280.00 399.97 290.97 0.38 500.00 5.00 280.00 499.74 390.74 1.51 600.00 7.50 280.00 599.14 490.14 3.40 702.06 10.05 280.00 700.00 591.00 6.11 Continue Build @ 3.5/ 100ft, 702ft MD, 700ft TVD 800.00 13.48 280.00 795.87 686.87 9.58 900.00 16.98 280.00 892.34 783.34 14.14 1,000.00 20.48 280.00 987.03 878.03 19.71 1,100.00 23.98 280.00 1,079.58 970.58 26.28 1,200.00 27.48 280.00 1,169.65 1,060.65 33.82 1,299.99 30.98 280.00 1,256.91 1,147.91 42.29 1,399.99 34.48 280.00 1,341.02 1,232.02 51.68 1,499.99 37.98 280.00 1,421.67 1,312.67 61.94 1,601.91 41.55 280.00 1,500.00 1,391.00 73.26 Sail @ 42° Inc : 1602ft MD, 1500ft TVD 1,628.63 41.55 280.00 1,520.00 1,411.00 76.34 Base Perm 1,701.91 41.55 280.00 1,574.84 1,465.84 84.78 Continue Buildfiurn @ 4.5/100ft , 1702ft MD, 157 5ft TVD 1,798.69 45.52 277.40 1,645.00 1,536.00 94.80 T3 1,799.99 45.57 277.37 1,645.91 1,536.91 94.92 1,899.99 49.73 275.04 1,713.26 1,604.26 102.86 1,999.99 53.93 272.98 1,775.05 1,666.05 108.32 2,099.99 58.16 271.13 1,830.90 1,721.90 111.26 2,166.31 60.98 270.00 1,864.49 1,755.49 111.82 Sail @ 61°I nc B 270°Azi : 2155ft MD, 1864ft TVD 2,199.99 60.98 270.00 1,880.83 1,771.83 111.82 2,299.99 60.98 270.00 1,929.34 1,820.34 111.82 2,305.48 60.98 270.00 1,932.00 1,823.00 111.82 K15 2,399.99 60.98 270.00 1,977.85 1,868.85 111.82 2,499.99 60.98 270.00 2,026.36 1,917.36 111.82 2,599.99 60.98 270.00 2,074.87 1,965.87 111.82 2,699.99 60.98 270.00 2,123.38 2,014.38 111.82 Map Map +E/-W Northing Easting DLSEV Vert Section (ft) (ft) Ift1 (°I100ft) Ift) 0.00 5,945,905.10 558,649.10 0.00 0.00 0.00 5,945,905.10 558,649.10 0.00 0.00 0.00 5,945,905.10 558,649.10 0.00 0.00 0.00 5,945,905.10 558,649.10 0.00 0.00 0.00 5,945,905.10 558,649.10 0.00 0.00 -2.15 5,945,905.46 558,646.95 2.50 -0.38 -8.59 5,945,906.55 558,640.50 2.50 -1.51 -19.31 5,945,908.35 558,629.77 2.50 -3.40 -34.64 5,945,910.94 558,614.41 2.50 -6.11 -54.31 5,945,914.25 558,594.73 3.50 -9.58 -80.17 5,945,918.61 558,568.83 3.50 -14.14 -111.79 5,945,923.94 558,537.17 3.50 -19.71 -149.04 5,945,930.22 558,499.88 3.50 -26.28 -191.78 5,945,937.42 558,457.08 3.50 -33.82 -239.86 5,945,945.52 558,408.94 3.50 -42.29 -293.10 5,945,954.49 558,355.63 3.50 -51.68 -351.30 5,945,964.30 558,297.37 3.50 -61.94 -415.48 5,945,975.12 558,233.10 3.50 -73.26 -432.94 5,945,978.06 558,215.62 0.00 -76.34 -480.80 5,945,986.12 558,167.70 0.00 -84.78 -546.67 5,945,995.63 558,101.76 4.50 -94.80 -547.59 5,945,995.75 558,100.84 4.50 -94.92 -621.05 5,946,003.11 558,027.33 4.50 -102.86 -699.45 5,946,007.96 557,948.90 4.50 -108.32 -782.32 5,946,010.26 557,866.01 4.50 -111.26 -839.49 5,946,010.37 557,808.84 4.50 -111.82 -868.94 5,946,010.14 557,779.40 0.00 -111.82 -956.39 5,946,009.46 557,691.96 0.00 -111.82 -961.19 5,946,009.42 557,687.16 0.00 -111.82 -1,043.83 5,946,008.78 557,604.53 0.00 -111.82 -1,131.28 5,946,008.10 557,517.09 0.00 -111.82 -1,218.72 5,946,007.41 557,429.66 0.00 -111.82 -1,306.17 5,946,006.73 557,342.23 0.00 -111.82 4/14/2006 9:43:58AM Page 4 of 9 COMPASS 2003.11 Build 50 ~~p~llt~ ~~ ' ` ~ ~ r~ - ~ Halliburton Energy Servic es ~~L~~~~~~~~y ~Ot14CO F~11~~t5 Planning Report -Geographic --~------ ~RY tlrilllir~ Servhess Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-156 Design: 1J-156 (wp05) Planned Survey 1J-156 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +EI-W Northing Easting DLSEV Vert Section (ftl (°) l°l (ftl lftl Iftl 1ft) 1ft1 (ft) (°/100ft) (ftl 2,791.96 60.98 270.00 2,168.00 2,059.00 111.82 -1,386.59 5,946,006.11 557,261.81 0.00 -111.82 10 3/4" @ 2792ft MD, 2168ft TVD - 2206ft FSL & 3946ft FEL -Sec 35 - T1 1 N - R10E - T 3 + 550 -10 3/4" 2,799.99 60.98 270.00 2,171.89 2,062.89 111.82 -1,393.61 5,946,006.05 557,254.79 0.00 -111.82 2,899.99 60.98 270.00 2,220.41 2,111.41 111.82 -1,481.06 5,946,005.37 557,167.36 0.00 -111.82 2,999.99 60.98 270.00 2,268.92 2,159.92 111.82 -1,568.50 5,946,004.69 557,079.93 0.00 -111.82 3,016.31 60.98 270.00 2,276.84 2,167.84 111.82 -1,582.78 5,946,004.58 557,065.65 0.00 -111.82 Continue Turn @ 4.6/100ft , 3016ft MD, 2277ft TVD 3,099.99 60.47 265.72 2,317.77 2,208.77 109.10 -1,655.69 5,946,001.30 556,992.77 4.50 -109.10 3,199.99 60.04 260.56 2,367.41 2,258.41 98.75 -1,741.85 5,945,990.27 556,906.70 4.50 -98.75 3,299.99 59.81 255.37 2,417.55 2,308.55 80.73 -1,826.44 5,945,971.59 556,822.26 4.50 -80.73 3,399.99 59.79 250.16 2,467.88 2,358.88 55.13 -1,908.94 5,945,945.36 556,739.97 4.50 -55.13 3,499.99 59.97 244.96 2,518.09 2,409.09 22.13 -1,988.85 5,945,911.74 556,660.33 4.50 -22.13 3,599.99 60.36 239.79 2,567.86 2,458.86 -18.07 -2,065.66 5,945,870.95 556,583.84 4.50 18.07 3,705.80 60.98 234.38 2,619.73 2,510.73 -68.18 -2,143.06 5,945,820.24 556,506.84 4.50 68.18 Sail @ 61°Inc & 234°Azi : 3706ft M D, 2620ft TVD 3,799.98 60.98 234.38 2,665.41 2,556.41 -116.14 -2,210.01 5,945,771.76 556,440.28 0.00 116.14 3,899.98 60.98 234.38 2,713.92 2,604.92 -167.07 -2,281.09 5,945,720.28 556,369.60 0.00 167.07 3,999.98 60.98 234.38 2,762.43 2,653.43 -218.00 -2,352.18 5,945,668.80 556,298.92 0.00 218.00 4,099.98 60.98 234.38 2,810.94 2,701.94 -268.93 -2,423.26 5,945,617.33 556,228.24 0.00 268.93 4,151.64 60.98 234.38 2,836.00 2,727.00 -295.25 -2,459.99 5,945,590.73 556,191.73 0.00 295.25 Ungu C 4,199.98 60.98 234.38 2,859.45 2,750.45 -319.86 -2,494.35 5,945,565.85 556,157.56 0.00 319.86 4,299.98 60.98 234.38 2,907.96 2,798.96 -370.79 -2,565.43 5,945,514.37 556,086.88 0.00 370.79 4,339.80 60.98 234.38 2,927.27 2,818.27 -391.07 -2,593.73 5,945,493.88 556,058.74 0.00 391.07 Continue Buil dlTurn @ 4.5/100ft , 4340ft MD, 2927ft TVD 4,399.98 61.27 231.30 2,956.34 2,847.34 -422.90 -2,635.73 5,945,461.73 556,017.00 4.50 422.90 4,499.98 61.89 226.24 3,003.96 2,894.96 -480.85 -2,701.83 5,945,403.27 555,951.36 4.50 480.85 4,525.62 62.08 224.95 3,016.00 2,907.00 -496.68 -2,718.00 5,945,387.31 555,935.32 4.50 496.68 Ugnu B 4,599.98 62.70 221.24 3,050.47 2,941.47 -544.80 -2,763.00 5,945,338.85 555,890.69 4.50 544.80 4,699.98 63.68 216.32 3,095.60 2,986.60 -614.36 -2,818.86 5,945,268.87 555,835.39 4.50 614.36 4,705.41 63.74 216.05 3,098.00 2,989.00 -618.28 -2,821.73 5,945,264.92 555,832.54 4.50 618.28 Ugnu A 4,799.98 64.83 211.48 3,139.05 3,030.05 -689.10 -2,869.06 5,945,193.74 555,785.77 4.50 689.10 4,899.98 66.13 206.75 3,180.57 3,071.57 -768.56 -2,913.30 5,945,113.95 555,742.16 4.50 768.56 4,999.98 67.58 202.11 3,219.89 3,110.89 -852.25 -2,951.29 5,945,029.97 555,704.82 4.50 852.25 5,034.75 68.11 200.53 3,233.00 3,124.00 -882.25 -2,963.00 5,944,999.89 555,693.34 4.50 882.25 K13 5,099.98 69.15 197.58 3,256.77 3,147.77 -939.66 -2,982.82 5,944,942.33 555,673.97 4.50 939.66 5,199.98 70.84 193.14 3,291.00 3,182.00 -1,030.25 -3,007.68 5,944,851.56 555,649.82 4.50 1,030.25 5,299.98 72.64 188.79 3,322.35 3,213.35 -1,123.45 -3,025.73 5,944,758.23 555,632.51 4.50 1,123.45 5,399.98 74.52 184.53 3,350.63 3,241.63 -1,218.69 -3,036.84 5,944,662.91 555,622.14 4,50 1,218.69 5,499.98 76.49 180.35 3,375.67 3,266.67 -1,315.39 -3,040.95 5,944,566.19 555,618.78 4:50 1,315.39 5,525.44 77.00 179.30 3,381.50 3,272.50 -1,340.18 -3,040.87 5,944,541.41 555,619.05 4.50 1,340.18 Sail @ 77°Inc & 179°Azi : 5525ft MD, 3382ft TVD 5,599.98 77.00 179.30 3,398.27 3,289.27 -1,412.80 -3,039.98 5,944,468.81 555,620.50 0.00 1,412.80 4/14/2006 9:43:58AM Page 5 of 9 COMPASS 2003.11 Build 50 ~ ~ ~--' , Halliburton Energy Service s t-tglLLl~URTON ~~~~~~'~~~~~ Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Weil: Plan 1J-156 Survey Calculation Method: Minimum Curvature Weilbore: 1 J-156 Design: 1 J-156 (wp05) Planned Survey 1J-156 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section lft) 1°) (°) (ft) (ft) (ft) (ft) lft) Ift) (°I100ft) (ft) 5,625.44 77.00 179.30 3,404.00 3,295.00 -1,437.61 -3,039.68 5,944,444.00 555,621.00 0.00 1,437.61 Wsak D -1J-156 T1 Dtop (wp05} 5,699.98 77.00 179.30 3,420.77 3,311.77 -1,510.23 -3,038.79 5,944,371.40 555,622.45 0.00 1,510.23 5,799.98 77.00 179.30 3,443.26 3,334.26 -1,607.66 -3,037.60 5,944,273.99 555,624.40 0.00 1,607.66 5,834.38 77.00 179.30 3,451.00 3,342.00 -1,641.17 -3,037.19 5,944,240.48 555,625.07 0.00 1,641.17 Wsak C 5,892.44 77.00 179.30 3,464.06 3,355.06 -1,697.74 -3,036.50 5,944,183.92 555,626.20 0.00 1,697.74 Build @ 5°/100ft to 80° Inc - 5892ft MD, 3464ft TVD 5,899.98 77.38 179.30 3,465.73 3,356.73 -1,705.09 -3,036.41 5,944,176.58 555,626.35 5.00 1,705.09 5,952.44 80.00 179.30 3,476.02 3,367.02 -1,756.53 -3,035.78 5,944,125.15 555,627.38 5.00 1,756.53 Sail @ 80° Inc : 5952ft MD, 3476ft TVD -Wsak B 5,999.98 80.00 179.30 3,484.28 3,375.28 -1,803.34 -3,035.21 5,944,078.35 555,628.32 0.00 1,803.34 6,099.98 80.00 179.30 3,501.64 3,392.64 -1,901.81 -3,034.01 5,943,979.90 555,630.29 0.00 1,901.81 6,188.42 80.00 179.30 3,517.00 3,408.00 -1,988.91 -3,032.95 5,943,892.82 555,632.03 0.00 1,988.91 Wsak A4 6,199.98 80.00 179.30 3,519.01 3,410.01 -2,000.28 -3,032.81 5,943,881.45 555,632.26 0.00 2,000.28 6,299.97 80.00 179.30 3,536.37 3,427.37 -2,098.76 -3,031.60 5,943,783.00 555,634.23 0.00 2,098.76 6,399.97 80.00 179.30 3,553.74 3,444.74 -2,197.23 -3,030.40 5,943,684.55 555,636.20 0.00 2,197.23 6,453.33 80.00 179.30 3,563.00 3,454.00 -2,249.77 -3,029.76 5,943,632.02 555,637.25 0.00 2,249.77 Wsak A3 6,499.97 80.00 179.30 3,571.10 3,462.10 -2,295.70 -3,029.20 5,943,586.10 555,638.17 0.00 2,295.70 6,599.97 80.00 179.30 3,588.47 3,479.47 -2,394.17 -3,027.99 5,943,487.64 555,640.14 0.00 2,394.17 6,699.97 80.00 179.30 3,605.83 3,496.83 -2,492.65 -3,026.79 5,943,389.19 555,642.11 0.00 2,492.65 6,743.44 80.00 179.30 3,613.38 3,504.38 -2,535.45 -3,026.27 5,943,346.40 555,642.96 0.00 2,535.45 Build @ 5°/100ft to 88° Inc - 6743ft MD, 3613ft TVD 6,799.97 82.83 179.30 3,621.82 3,512.82 -2,591.34 -3,025.58 5,943,290.52 555,644.08 5.00 2,591.34 6,863.44 86.00 179.30 3,628.00 3,519.00 -2,654.50 -3,024.81 5,943,227.38 555,645.34 5.00 2,654.50 7 518" @ 6863ft MD, 3628ft TVD : 4719ft FSL & 307ft FEL - Sec 3 - T10N - R10E -Sail @ 86° Inc : 6863ft MD, 3628ft TVD -Wsak A2 - 7 5/8" -1J 6,883.44 86.00 179.30 3,629.39 3,520.39 -2,674.45 -3,024.57 5,943,207.44 555,645.74 0.00 2,674.45 Build @ 3.00/100ft , 6883.45ft MD, 3529.39ft TVD 6,899.97 86.49 179.25 3,630.47 3,521.47 -2,690.94 -3,024.36 5,943,190.95 555,646.08 3.00 2,690.94 6,999.97 89.48 178.98 3,633.98 3,524.98 -2,790.85 -3,022.82 5,943,091.06 555,648.39 3.00 2,790.85 7,032.26 90.45 178.89 3,634.00 3,525.00 -2,823.14 -3,022.23 5,943,058.78 555,649.24 3.00 2,823.14 Continue Geo-Steering In Upper A2 Sand. 7032ft MD. 3634ft TVD 7,097.08 90.45 178.89 3,633.50 3,524.50 -2,887.94 -3,020.97 5,942,994.00 555,651.00 0.00 2,887.94 1J-156 T2 (wp05) 7,099.97 90.29 178.90 3,633.48 3,524.48 -2,890.83 -3,020.92 5,942,991.11 555,651.08 5.50 2,890.83 7,199.97 84.80 179.23 3,637.77 3,528.77 -2,990.69 -3,019.29 5,942,891.27 555,653.48 5.50 2,990.69 7,259.25 81.54 179.43 3,644.82 3,535.82 -3,049.53 -3,018.60 5,942,832.44 555,654.63 5.50 3,049.53 7,299.97 81.54 179.43 3,650.81 3,541.81 -3,089.81 -3,018.20 5,942,792.17 555,655.35 0.00 3,089.81 7,335.76 81.54 179.43 3,656.07 3,547.07 -3,125.21 -3,017.85 5,942,756.78 555,655.98 0.00 3,125.21 7,399.97 84.75 179.39 3,663.73 3,554.73 -3,188.95 -3,017.19 5,942,693.06 555,657.13 5.00 3,188.95 7,499.97 89.75 179.33 3,668.52 3,559.52 -3,288.79 -3,016.07 5,942,593.23 555,659.03 5.00 3,288.79 7,549.33 92.22 179.30 3,667.67 3,558.67 -3,338.14 -3,015.48 5,942,543.90 555,660.00 5.00 3,338.14 4/14/2006 9:43:58AM Page 6 of 9 COMPASS 2003.11 Build 50 ~''r~C.~ ' ~ ~ ~ - , Halliburton Energy Service s ~~q~L~~~~~-per C4l1CtCC3 ~1l~~l5 Planning Report -Geographic --- -- ~nY OcilUng Servtrss Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-156 -Slot 1 J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Welfbore: 1 J-156 Design: 1 J-156 (wp05) Planned Survey 1J-156 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +W-S +E!-W Northing Easting DLSEV Vert Section Iftl (°) (°) Ift) (ft) (ft) lft) (ft) (ft) (°I100ft) (ft) 7,599.97 92.22 179.30 3,665.71 3,556.71 -3,388.74 -3,014.86 5,942,493.31 555,661.01 0.00 3,388.74 7,649.33 92.22 179.30 3,663.80 3,554.80 -3,438.06 -3,014.26 5,942,444.00 555,662.00 0.00 3,438.06 1J-156 T3 (wp05) 7,658.29 92.40 179.30 3,663.44 3,554.44 -3,447.01 -3,014.15 5,942,435.05 555,662.18 2.00 3,447.01 7,699.97 92.40 179.30 3,661.69 3,552.69 -3,488.65 -3,013.64 5,942,393.42 555,663.01 0.00 3,488.65 7,799.97 92.40 179.30 3,657.51 3,548.51 -3,588.55 -3,012.41 5,942,293.54 555,665.02 0.00 3,588.55 7,899.97 92.40 179.30 3,653.32 3,544.32 -3,688.46 -3,011.19 5,942,193.66 555,667.02 0.00 3,688.46 7,999.97 92.40 179.30 3,649.14 3,540,14 -3,788.36 -3,009.97 5,942,093.77 555,669.02 0.00 3,788.36 8,099.97 92.40 179.30 3,644.95 3,535.95 -3,888.27 -3,008.74 5,941,993.89 555,671.02 0.00 3,888.27 8,148.92 92.40 179.30 3,642.90 3,533.90 -3,937.17 -3,008.14 5,941,945.00 555,672.00 0.00 3,937.17 1J-156 T4 (wp05) 8,199.97 91.90 179.42 3,640.98 3,531.98 -3,988.18 -3,007.58 5,941,894.00 555,672.97 1.00 3,988.18 8,211.01 91.80 179.45 3,640.63 3,531.63 -3,999.21 -3,007.47 5,941,882.97 555,673.16 1.00 3,999.21 8,299.97 91.80 179.45 3,637.84 3,528.84 -4,088.13 -3,006.62 5,941,794.07 555,674.70 0.00 4,088.13 ~ 8,317.05 91.80 179.45 3,637.30 ~ 3,528.30 -4,105.20 -3,006.45 5,941,777.00 555,675.00 0.00 4,105.20 BHL @ 8317ft MD, 3637f TVD : 3268ft FSL & 290ft FEL -Sec 3 - T10N - R10E - 41/2" -1J-156 T5 Toe (wp05) - 4/14/2006 9:43:58AM Page 7 of 9 COMPASS 2003.11 Build 50 ~?~~~~ ~` ~ Haliiburton Energy Services ~~~~~~~~~~~~ Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1 J-156 Wellbore: 1 J-156 Design: 1J-156 (wp05) ~-[A1..~.18ta~"Tt~N Sparey Drilling Sarvtcss Local Co-ordinate Reference: WeII Plan 1 J-156 -Slot 1 J-156 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Geologic Targets 1 J-156 TVD Target Name +N/-S +E/-W Northing Fasting (ft) -Shape ft ft (ft) (ft) 3,628.00 1J-156 DD Poly (wp05) -2,654.11 -3,074.82 5,943,227.38 555,595.34 - Polygon Point 1 0.00 0.00 5,943,227.38 555,595.34 Point 2 0.24 -19.95 5,943,207.44 555,595.74 Point 3 2.59 -168.64 5,943,058.78 555,599.25 Point 4 3.84 -233.44 5,942,994.00 555,601.00 Point 5 6.21 -395.04 5,942,832.44 555,604.63 Point 6 6.96 -470.72 5,942,756.78 555,605.97 Point 7 9.33 -683.65 5,942,543.90 555,610.00 Point 8 10.55 -783.56 5,942,444.00 555,612.00 Point 9 10.65 -792.52 5,942,435.05 555,612.17 Point 10 16.67 -1,282.67 5,941,945.00 555,622.00 Point 11 17.34 -1,344.72 5,941,882.97 555,623.16 Point 12 18.36 -1,450.71 5,941,777.00 555,625.00 Point 13 118.37 -1,451.49 5,941,777.00 555,725.00 Point 14 117:35 -1,345.50 5,941,882.97 555,723.16 Point 15 116.67 -1,283.45 5,941,945.00 555,722.00 Point 16 110.66 -793.30 5,942,435.05 555,712.17 Point 17 110.56 -784.34 5,942,444.00 555,712.00 Point 18 109.34 -684.42 5,942,543.90 555,710.00 Point 19 106.97 -471.49 5,942,756.78 555,705.97 Point 20 106.19 -395.82 5,942,832.44 555,704.60 Point 21 103.84 -234.22 5,942,994.00 555,701.00 Point 22 102.59 -169.42 5,943,058.78 555,699.25 Point 23 100.25 -20.73 5,943,207.44 555,695.74 Point 24 100.01 -0.78 5,943,227.38 555,695.34 3,663.80 1J-156 T3 (wp05) -3,438.06 -3,014.26 5,942,444.00 555,662.00 - Point 3,637.30 1J-156 T5 Toe (wp05) -4,105.20 -3,006.45 5,941,777.00 555,675.00 - Point 3,642.90 1J-156 T4 (wp05) -3,937.17 -3,008.14 5,941,945.00 555,672.00 - Point 3,404.00 1J-156 T1 Dtop (wp05) -1,437.61 -3,039.68 5,944,444.00 555,621.00 - Point 3,633.50 1J-156 T2 (wp05) -2,887.94 -3,020.97 5,942,994.00 555,651.00 - Point I Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) lft) (") (") so.oo 80.00 20 2s 2,791.96 2,168.00 10-3/4 13-112 6,863.44 3,628.00 7-518 9-718 8,317.04 3,637.30 4-112 6-3/4 4/14/2006 9:43:58AM Page 8 of 9 COMPASS 2003.11 Build 50 ~~~~ ~ ~ " -' ' Halliburton Energy Service s ~p~~~~~~p~~-~~y COi ~OCQ ~ tl~~t~35 Planning Report -Geographic ------- ______.... Alaska Sperry Orilting Serves Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-156 Design: 1 J-156 (wp05) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W Ift) (°) 1°) (ft) !ft) (ft) Name 1,628.63 41.55 280.00 1,520.00 76.34 -432.94 Base Perm 1,798.69 45.52 277.40 1,645.00 94.80 -546.67 T3 2,305.48 60.98 270.00 1,932.00 111.82 -961.19 K75 2,791.96 60.98 270.00 2,168.00 111.82 -1,386.59 T3 + 550 4,151.64 60.98 234.38 2,836.00 -295.25 -2,459.99 Ungu C 4,525.62 62.08 224.95 3,016.00 -496.68 -2,718.00 Ugnu B 4,705.41 63.74 216.05 3,098.00 -618.28 -2,821.73 Ugnu A 5,034.75 68.11 200.53 3,233.00 -882.25 -2,963.00 Kf3 5,625.44 77.00 179.30 3,404.00 -1,437.61 -3,039.68 Wsak D 5,834.38 77.00 179.30 3,451.00 -1,641.17 -3,037.19 Wsak C 5,952.43 80.00 179.30 3,476.02 -1,756.51 -3,035.78 Wsak B 6,188.42 80.00 179.30 3,517.00 -1,988.91 -3,032.95 Wsak A4 6,453.33 80.00 179.30 3,563.00 -2,249.77 -3,029.76 Wsak A3 6,863.44 86.00 179.30 3,628.00 -2,654.50 -3,024.81 Wsak AZ 4/14/2006 9:43:58AM Page 9 of 9 COMPASS 2003.11 Build 50 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-156 1 J-156 1 J-156 (wp05) Anticollision Report 14 April, 2006 ALLIIE~RC~~ Sperm Q~tling Services ~~~~~~ ~' oN N~ ~o ~~ c~ Jr r C a °e auZi J arp Z Q p ~ Lei J i n J 9 V ~ O10 0.~~ a N ~Wn a ~e C m Z~ ~e ~g O NdN.-. N ~ n ~ 6 ~ p n ; 2 Z H yny ~ O T N - 2 ro' O p ~ c f N ~ Cd ~ LL A . ~ ~ V v ~Ec z ~z'Ed` ot_ m arc eg V v~v~ ~ g 6 ~ p~ Y - Cdr p E 'u F ~ ~ U ~ ~ Y ~ yy > ~ ~ 4 C ~ ?~ L . C~~}-'. 3 '~-- ~8 ~~n o ~ ~ ~g~ W~~ O 0 N d O r ~ N p. O 3 ~ ~ ; 3 a ,~ ` O C/ N ~ O~ ~ O ~ ~\ O 7 ~ ~\ ~ \ ` \ ~x - _ . 7 ~'''' / e~ ,; ,: o II. / N ~ I ~ I C ~ m ~ I ~ I C ~ ~ ~ a ~ i ~/ 3 O a r 0 0 '7 r R a W o_ N n n 3 - - 3 a Nqi g p ; ... ; H H H H ~ H ~ i °nwe~°n V ~ m~~i1N~00~F r yoo~G oie~~ae~o~ n viti vri n: viN meo .nmo ~ n•q~ mom.-~.-waNO. ~°. gn nn °n gnna O O O O o b 0 O O O O y my O N O O O b o~ O ~ 0 0 0 0 o O N O m o H O b 0 0 0 ~o o~emo~oeoee dov~oeogo4c~c N Q o o N n c V o V o 0 0 o ul o N O n o ~n o N O tV o r e J v1(1~ ~ 3oebdmOAOAmbNnNON~i Onib a~pf N~~d< Wo ~oe~viomm~pe~m ~~rav.~+om~uiaamn.g' U ~oe m m nyNV~mnN~oO~NN e ~ ~ me W 3oe ~~~ m~n M~~ wanna~m e poeooQd~n HN000 n onovei a`~o o~no,m~ m~~n,r roe°o °n .°c N.°-' aa~e ei eo oiti ~~u u~~e ~.O.p ~wnwei n~nnrein n eo v+~ n eo ~_ ~~~~ cgSovv'i vv~imnmm °ooeeee°o,~a ~i~«Nagem -e °`va~°e °m ~°o ~°o~nn°m °w mm°a °mm `m mmmwm `m ~ g g~ m m wi n m m V V~ 0 0< V N o r ~ n n n m o C «Se nn«mv°'ia~mr`"im~n~'~iOrom' ~ ~ H n h V N N h N b vp u n n n n n m N~wnanronam~~~~~~~~~~wwrHnNN c~ C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O~ O N O 0 0 0 0 0 0 0 0 0 0 0 O ~ O~ O~ ~f1 r 0 0 0 0 0 0 0 0 0 ~ N th ~ N ~n r .- ~ ~ N M v ~n co r ao rn ~ ~ .- U V I I I( f l l l l l l l l l ~ ~ ~ N~ O~ O~ O~ 0 0 0 0 0 0 0 0 0 0 0 N~ r S~ N` O O O O O O O O O O S i ~ O ~ .- N r> a ~n co r m rn o .- f ~ N C N C1 'S G. ~' ~ O O m x C Z O 3 N 1D u L 4 t ~ N O ... ~ 0 0 n o 0 ~O O o =m N o Z o z ~mem~ O ~¢~rcU ~ A C ~ G j ~ a '- O =~o~E LL ~aviaf z W Y d d b 9 G d d c c c° W d~~ rc ~~~ of LL rcrcrcz"; z ~Sh£'A zZ? °~ m ~ ~ U g y O C N ~ b~ A U ~ C] ~ I / N • / Halliburton Energy Services ~OIIOC~rI Il~~lp$ Anticollision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1 J-156 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-156 Database: Reference Design: 1 J-156 (wp05) Offset TVD Reference: HALE.lBURTOIN Sperry Drilling Services Well Plan 1J-156 -Slot 1J-156 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-156 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval SO.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,028.95ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 4/14/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-156 (wp05) (1J-156) CB-GYRO-MS Camera based gyro multishot 800.00 8,317.05 1J-156 (wp05) (1J-156) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2006 10:2831AM Page 2 of 6 COMPASS 2003.11 Build 50 F~ 4 ~ 't '~ COI'lOCO~'tl~~l~"15 Alaska • Halliburton Energy Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1 J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1 J-156 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-156 Database: Reference Design: 1J-156 (wp05) Offset ND Reference: HALLEBtJE~TOIN Sperry Driiling Services Well Plan 1J-156 -Slot 1J-156 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db 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. 1J-03 - 1J-03 - 1J-03 142.88 150.00 141.86 2.52 139.34 Pass -Major Risk 1 J-09 - 1 J-09 - 1 J-09 293.93 300.00 60.42 5.37 55.04 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 2,037.36 2,150.00 103.84 49.11 66.83 Pass -Major Risk 1 J-101 - 1 J-101 - 1 J-101 396.88 400.00 212.22 8.62 203.60 Pass -Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 396.88 400.00 212.22 8.62 203.60 Pass -Major Risk 1J-101 - 1J-101 L1 P61 - 1J-101 L1 PB1 396.88 400.00 212.22 8.62 203.60 Pass- Major Risk 1J-101 - 1J-101 L2 - 1J-101 L2 396.88 400.00 212.22 8.62 203.60 Pass -Major Risk 1J-101 - 1J-101PB1 - 1J-101PB1 396.88 400.00 212.22 8.62 203.60 Pass- Major Risk 1 J-154 - 1 J-154 - 1 J-154 500.45 500.00 44.00 11.00 33.00 Pass -Major Risk 1 J-154 - 1 J-154 L1 - 1 J-154 L1 500.45 500.00 44.00 11.00 33.00 Pass -Major Risk 1 J-154 - 1 J-154 L2 - 1 J-154 L2 500.45 500.00 44.00 11.00 33.00 Pass -Major Risk 1 J-159 - 1 J-159 - 1 J-159 496.96 500.00 63.58 10.94 52.64 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 496.96 500.00 63.58 10.94 52.64 Pass -Major Risk 1J-159 - 1J-159 L1 P61 - 1J-159 L1 PB1 496.96 500.00 63.58 10.94 52.64 Pass -Major Risk 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 PB2 496.96 500.00 63.58 10.94 52.64 Pass -Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 496.96 500.00 63.58 10.94 52.64 Pass -Major Risk 1J-159 - 1J-159 PB1 - 1J-159 PB1 496.96 500.00 63.58 10.94 52.64 Pass -Major Risk 1 J-164 - 1 J-164 - 1 J-164 541.56 550.00 183.63 11.92 171.71 Pass -Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 541.56 550.00 183.63 11.92 171.71 Pass -Major Risk 1J-164 - 1J-164 L2 - 1J-164 L2 541.56 550.00 183.63 11.92 171.71 Pass -Major Risk 1J-164 - 1J-164 L2 P61 - 1J-164 L2 PB1 541.56 550.00 183.63 11.92 171.71 Pass -Major Risk 1 J-166 - 1 J-166 - 1 J-166 444.18 450.00 222.62 9.81 212.82 Pass -Major Risk 1 J-166 - 1 J-166 L1 - 1 J-166 L1 444.18 450.00 222.62 9.81 212.82 Pass -Major Risk 1 J-166 - 1 J-166 L1 P61 - 1J-166 L1 P61 444.18 450.00 222.62 9.81 212.82 Pass -Major Risk 1J-166 - 1J-166 L2 - 1J-166 L2 444.18 450.00 222.62 9.81 212.82 Pass -Major Risk 1J-166 - 1J-166 L2 P61 - 1J-166 L2 PB1 444.18 450.00 222.62 9.81 212.82 Pass -Major Risk 1 J-168 - 1 J-168 - 1 J-168 347.84 350.00 260.98 7.61 253.38 Pass -Major Risk 1 J-168 - 1 J-168 L1 - 1 J-168 L1 347.84 350.00 260.98 7.61 253.38 Pass -Major Risk 1 J-168 - 1 J-168 L2 - 1 J-168 L2 347.84 350.00 260.98 7.61 253.38 Pass -Major Risk 1J-168 - 1J-168 L2 PB1 - 1J-168 L2 P61 347.84 350.00 260.98 7.61 253.38 Pass -Major Risk Plan 1 J-102 - 1 J-102 - 1 J-102 (wp06) 336.62 350.00 189.08 7.33 181.75 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp06) 336.62 350.00 189.08 7.33 181.75 Pass -Major Risk Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 (wp06) 336.62 350.00 189.08 7.33 181.75 Pass -Major Risk Pian 1 J-103 -Plan 1 J-103 - 1 J-103 (wp02) 348.01 350.00 177.78 7.55 170.24 Pass -Major Risk Plan 1 J-105 -Plan 1 J-105 - 1 J-105 (wp02) 347.71 350.00 158.16 7.54 150.62 Pass -Major Risk Plan 1 J-107 -Plan 1 J-107 - 1 J-107 (wp02) 347.38 350.00 148.33 7.54 140.79 Pass -Major Risk Plan 1J-109 -Plan 1J-109 - 1J-109 (wp05) 288.00 300.00 151.99 6.38 145.61 Pass -Major Risk Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) 346.61 350.00 167.48 7.52 159.96 Pass -Major Risk Plan 1 J-112 Kuparuk Prelim - 1 J-12 E Lateral - 1 J-12 334.39 350.00 177.20 7.29 169.91 Pass -Major Risk Pian 1J-112 Kuparuk Prelim - 1J-12 Pilot- 1J-12 Pilot 334.39 350.00 177.20 7.29 169.91 Pass -Major Risk Plan 1J-112 Kuparuk Prelim -Plan 1J-12 W Lateral 334.39 350.00 177.20 7.29 169.91 Pass -Major Risk Plan 1 J-115 -Plan 1 J-115 - 1 J-115 (wp02) 346.02 350.00 217.09 7.52 209.57 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDisposal 352.27 350.00 140.33 6.77 133.56 Pass -Major Risk Plan 1 J-152 - 1 J-152 - 1 J-152 452.48 450.00 100.62 9.82 90.80 Pass -Major Risk Plan 1 J-152 - 1 J-152 L1 - 1 J-152 L1 452.48 450.00 100.62 9.82 90.80 Pass -Major Risk Pian 1 J-152 - 1 J-152 L2 - 1 J-152 L2 452.48 450.00 100.62 9.82 90.80 Pass -Major Risk Plan 1J-152 - 1J-152 L2 PB1 - 1J-152 L2 PB1 452.48 450.00 100.62 9.82 90.80 Pass -Major Risk Plan 1J-152 - 1 J-152 PB1 - 1J-152 P61 452.48 450.00 100.62 9.82 90.80 Pass -Major Risk Plan 1J-152 - 1J-152 PB2 - 1J-152 PB2 452.48 450.00 100.62 9.82 90.80 Pass -Major Risk Plan 1J-156- 1J-156 L1 - 1J-156 L1 (wp05) 5,999.95 5,999.98 1.40 4.72 -1.91 FAIL- No Errors Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp05) 5,649.99 5,650.00 0.62 3.19 -1.87 FAIL- No Errors Plan 1 J-158 - 1 J-158 - 1 J-158 w 03 846.75 850.00 45.19 18.22 27.01 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2006 10;28;31AM Page 4 of 6 COMPASS 2003.11 Build 50 c ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-156 Well Error: O.OOft Reference Wellbore 1J-156 Reference Design: 1J-156 (wp05) Halliburton Energy Services HALLIBURT~N Anticollision Report Sperry Drllling Services Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 TYD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+g1)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: EDM 2003.11 Single User Db Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI 546.72 550.00 80.08 11.98 68.09 Pass -Major Risk Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel) 593.73 600.00 139.56 12.96 126.61 Pass -Major Risk Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) 593.73 600.00 139.56 12.86 126.71 Pass -Major Risk Plan 1 J-162 - 1J-162 L2 - 1 J-162 L2 (wp3.1) 593.73 600.00 139.56 12.86 126.71 Pass -Major Risk PIan1J-170-1J-170-1J-170(wp05) 5,266.79 5,350.00 274.06 104.90 169.94 Pass-Major Risk Plan 1J-170- 1J-170 L1 - 1J-170 L1 (wp05) 5,266.79 5,350.00 274.06 104.89 169.94 Pass- Major Risk Plan 1 J-170 - 1 J-170 L2 - 1J-170 L2 (wp05) 5,266.79 5,350.00 274.06 104.90 169.94 Pass -Major Risk Plan 1 J-173 Kuparuk - 1 J-73 E Lateral - 1 J-73 E Lat 5,671.20 5,499.98 215.70 106.44 112.25 Pass -Major Risk Plan 1J-173 Kuparuk- 1J-73 Kuparuk- 1J-73 W Lat 5,671.20 5,499.98 215.70 106.44 112.25 Pass- Major Risk Plan 1 J-173 Kuparuk - 1J-73 Pilot - 1 J-173 Pilot (wp 5,671.20 5,499.98 215.70 106.44 112.25 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 338.79 350.00 190.32 6.85 183.48 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 349.39 350.00 217.52 9.13 208.39 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 334.48 350.00 182.32 8.17 174.16 Pass -Major Risk WSP-1 S -WSP-1 S -WSP-1 S 386.63 400.00 191.16 11.95 179.37 Pass -Major Risk WSP-20 -WSP-20 -WSP-20 549.06 550.00 188.11 13.61 174.50 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2006 10:28,~31AM Page 5 of 6 COMPASS 2003.11 Build 50 In, I ~ ~ ~ ~ ~~. ~_n. s ~ ~ a ~t~ • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-156 -Slot 1J-156 Plan: 1J-156 (wp05) 1/4 Mile Scan 14 April, 2006 Spenly Driliing S~irvices ~'3 ~ k~~ 3750 3000 1 1 J-156 1 /~ C_ O O tf) t t r O Z 0 1J-1f ConocoPhillips Alaska T ~"~zimu;hs to True North Magnetic North: 24.04° Magnetic Field Strength: 57564.2nT Dip Angle: 80.77° Date: 6/30/2006 Model: BGGM2005 -7500 -6750 -6000 -5250 -4500 -3750 -3pQ0 _._ 225A : 1 X00. - -750 0 750 1500 2250 3000 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-156 Wel I bore: 1 J-156 Plan: 1 J-156 (wp05) i wells that may be drilled prior o i6 are the 1 J-168, 1 J-170 Closest in POOL Closest A roach: Reference Well : 1J-156 w 05 Plan Offset Well: 1J -170 w 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist C}ist Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (180° Comments POOL Min Distance POOL Min Distance (3765.83 ft) in POOL (3765.83 ft) in POOL (6863 - 8317.05 MD) (6863 - 8317.05 MD) to 1J-170 (wp05) to 1J-156 (wp05) Plan 3765.83 6863.44 86 179.3 3519.002 5943227 555645.3 2654.498 (7680-12508.5 MD) 7680.87 85 2 3510.033 5946975 555284.3 -1096.696 (7680-12508.5 MD) Closest A roach: Reference Well : 1J-156 w 05 Plan Offset Well: 1J -168 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. ' ? ~~ De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments POOL Min Distance POOL Min Distance (4362.63 ft) in POOL (4362.63 ft) in POOL (6863 - 8317.05 MD) (6863 - 8317.05 MD) to 1 J-168 (8229 - to 1 J-156 (wp05) Plan 4362.63 !'?1-' 6863.44 86 179.3 3519.002 5943227 555645.3 2654.498 12995 MD) 8229 85.19 4.29 3357.63 5947221 553897.7 -1353.158 (8229-12995 MD) Closes t A roach: Reference Well : 1J-156 w 05 Plan Offset Well: 1J -152 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)!S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + NV - 180° Comments De th Incl. An le TRUE Azi. TVD E + /W -) 180° Comments POOL Min Distance POOL Min Distance (1245.69 ft) in POOL (1245.69 ft) in POOL (6863 - 8317.05 MD) (6863 - 8317.05 MD) to 1J-152 (6523- to 1J-156 (wp05) Plan 1245.69 ".._ F? " 7750 92.4 179.3 3550.513 5942343 555664 3538.657 10053 MD) 9225 89.76 179.62 3523.391 5942360 556909.3 3531.25 (6523-10053 MD) • POOL Summary156.x1s 4/14/2006 2:07 PM Closest in POOL ^.,.,~/ ..~-~,'~ {,~ a+ ,. ..~, v «*`~' ~,., .~ r Closest A roach: Reference Well : 1J-156 L1 w 05 Plan Offset Well: 1J -.170 L1 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. TVD E(+)/W(_) (180°) Comments Depth Incl. An le TRUE Azi. ND E(+}/W(-) (180°) Comments POOL Min Distance POOL Min Distance (1809.22 ft) in POOL (1809.22 ft) in POOL (5952 - 12994.67 MD) (5952 - 12994.67 MD) to 1 J-156 L1 (wp05) to 1 J-170 L7 (wp05) Plan (6583 - 1809.22 5952.45 80 179.3 3367.031 5944125 555627.3 1756.609 (6583-12648.92 MD) 6583.88 80 2 3325.02 5945895 555255 -16.27184 12648.92 MD) Closest A roach: Reference Well : 1J-156 L1 w 05 Plan Offset Well: 1J -168 L1 Coords. - Coords. - ASP ASP 3-D ctr-ct 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(+)NV(-) (180°) Comments OOL Min Distance POOL Min Distance (2648.5 ft) in POOL (2648.5 ft) in POOL (5952 - 12994.67 MD) (5952 - 12994.67 MD) to 1 J-156 L1 (wp05) to 1 J-168 L1 (7145 - Plan (7145 - 12967 .2648.5 5952.45 80 179.3 3367.031 5944125 555627.3 1756.609 12967 MD) 7145 80.15 354.91 3185.22 5946152 553933.2 -284.3089 MD) Closes t A roach: Reference Well : 1J-156 L1 w 05 Plan Offset Well: 1J -152 L1 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments P L Min Distance POOL Min Distance (1189.27 ft) in POOL (1189.27 ft) in POOL (5952 - 12994.67 MD) (5952 - 12994.67 MD) to 1J-156 L1 (wp05) ~ to 1 J-152 L1 (5747 - Plan (5747 - 13408 1189.27 1 11125 91.59 179.24 3295.369 5938958 555733.6 6924.035 13408 MD) 12600 90.46 179.29 3318.65 5938978 556922.4 6913.359 MD) POOL Summary156L1.xls 4/14/2006 2:16 PM • • Closest in POOL ~v, _, i' w w'% t Closest A roach: Reference Well : 1J-156 L2 w 05 Plan Offset Well: 1J -170 L2 w 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. ! }is- Depth Incl. Angle TRUE Azi. TVD E(+)/W(_) (180°) Comments Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (1078.06 ft) in POOL (1D78.06 ft) in POOL (5625 - 12596.01 MD) (5625 - 12596.01 MD) to 1 J-156 L2 (wp05) / to 1J-170 L2 (wp05) Plan (6138 - 1078.06 5625 77 179.3 3294.966 5944444 555620.9 1437.235 (6138-12736.28 MD) 6138.33 77 359.79 3238.07 5945458 555258.6 420.6319 12736.28 MD) Closest A roach: Reference Well : 1J-156 L2 w 05 Plan Offset Well: 1J -168 L2 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)!S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments De th Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments P L Min Distance POOL Min Distance (2146.81 ft) in POOL (2146.81 ft) in POOL (5625 - 12596.01 MD) (5625 - 12596.01 MD) to 1J-156 L2 (wp05) to 1J-168 L2 (6787 - Plan (6787 - 12959 2146.81 5625 77 179.3 3294.966 5944444 555620.9 1437.235 12959 MD) 6800 75.96 348.19 3109.278 5945820 553983.6 48.35481 MD) Closes t A roach: Reference Weli : 1J-156 L2 w 05 Plan Offset Well: 1J -152 L2 MWD Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. TVD E + /W - 180° Comments De th Incl. An le TRUE Azi. TVD E + /W - (180°) Comments P in Distance POOL Min Distance (1247.98 ft) in POOL (1247.98 ft) in POOL (5625 - 12596.01 MD) (5625 - 12596.01 MD) to 1 J-156 L2 (wp05) / to 1J-152 L2 MWD Plan (5403 - 7434.83 1247.98 5850 89.86 179.3 3321.18 5944221 555625.3 1660.229 (5403-7434.83 MD) 7325 90.88 179.32 3340.827 5944245 556872.9 1646.353 MD) POOLSummary1 4/14/2006 2:25 PM • • 1J-156~rillin~ Hazards S mmary (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, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low ,, Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure ~ Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming _~ ~ ~ 1J-156 Drilling Hazards Summary prepared by Mike Greener 5/4/2006 12:12 PM • ~~~I~tr CemCADE Preliminary Job Design 10 3/4" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/5/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,629' MD (1,520' TVD) Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,992' MD. Lead Slurry Minimum pump time: 210 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x (1629' - 80') x 3.50 (250% excess) = 1971.8 ft3 0.3637 ft3/ft x (1992' - 1629') x 1.35 (35% excess) = 178.2 ft3 109.2 ft3 + 1971.8 ft3+ 178.2 ft3 = 2259.2 ft3 2259.2 ft3 / 4.45 ft3/sk = 507.7 sks Round up to 510 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2792' - 1992') x 1.35 (35% excess) = 392.8 ft3 0.5400ft3/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 = 47°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 1,992' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,792' MD (2,168' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 402.4 57.5 90.8 DeepCRETE 6.0 77.7 12.9 103.7 Drop top plug 0.0 0.0 5.0 108.7 Water 5.0 20.0 4.0 112.7 Switch to rig pump 0.0 0.0 5.0 117.7 Mud 7.0 231.8 33.1 150.8 Slow & bump plug 3.0 9.0 3.0 153.8 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. SpacerProperfies: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 3 per 2 joints throughout the tail slurry column. ~~~~ • • Scl~amberger CemCADE *well cementing recommendation for 10 3/4" Surface Casing Operator : CPAI Well 1J-156 TLI Country :USA Field West Sak State :Alaska Prepared for :Mike Greener Location 1J Pad Proposal No. : V1 (wp05) Service Point Prudhoe Bay Date Prepared :May 05, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by :Mike Martin Phone (907) 263-4207 E-Mail Address martin13C~slb.com ~~~ Q C7 C ~G ~~U RT E Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and Vea[men[. The results depend on input data provided by the Operatorand estimates as to unknown data and can be no more accurate than [he model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of [he well, the reservoir, [he field and conditions affecting [hem. If [he Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ~!~.. . ~~~~ • • Client CPAI Well 1J-156TLI String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :2792.0 ft BHST : 46 degF Bit Size : 13 1/2 in Previous String MD OD Weight ID (ft) (in (Ib/ft) (in) 80.0 20 94.0 19.124 Landing Collar MD :2712.0 ft Casing/liner Shoe MD :2792.0 ft ~~I r~~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2792.0 10 3/4 40.0 45.5 9.950 M-65 2270 4230 STC Mean OH Diameter :13.500 in Mean Annular Excess :157.8 Mean OH Equivalent Diameter: 16.955 in Total OH Volume :757.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1629.0 13.500 250.0 18.681 2792.0 13.500 35.0 14.338 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1629.0 1520.3 29 0.3 2792.0 2168.0 46 1.0 1j-156 cementcfw; OS-052006 ; Loadcase 1075 Surface ; Version wcstem45_89 Page 2 ~~IGLNAL • ~ Client CPAI Well 1J-156TLI String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Max. Devi ation Angle : 61 deg Max. DLS :4.502 deg/100ft MD ft) Directional Survey Data TVD Deviation Azimuth (ft) (deg) (de) Dogleg Sev. (de /100ft 0.0 0.0 0.0 0.0 0.000 80.0 80.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 2.5 280.0 2.500 500.0 499.7 5.0 280.0 2.500 600.0 599.1 7.5 280.0 2.500 702.1 700.0 10.1 280.0 2.499 800.0 795.9 13.5 280.0 3.502 900.0 892.3 17.0 280.0 3.500 1000.0 987.0 20.5 280.0 3.500 1100.0 1079.6 24.0 280.0 3.500 1200.0 1169.7 27.5 280.0 3.500 1300.0 1256.9 31.0 280.0 3.500 1400.0 1341.0 34.5 280.0 3.500 1500.0 1421.7 38.0 280.0 3.500 1601.9 1500.0 41.5 280.0 3.503 1701.9 1574.8 41.5 280.0 0.000 1800.0 1645.9 45.6 277.4 4.495 1900.0 1713.2 49.7 275.0 4.502 2000.0 1775.0 53.9 273.0 4.501 2100.0 1830.9 58.2 271.1 4.499 2166.3 1864.5 61.0 270.0 4.499 2200.0 1880.8 61.0 270.0 0.000 2300.0 1929.3 61.0 270.0 0.000 2400.0 1977.8 61.0 270.0 0.000 2500.0 2026.3 61.0 270.0 0.000 2600.0 2074.8 61.0 270.0 0.000 2700.0 2123.4 61.0 270.0 0.000 2792.0 2168.0 61.0 270.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (Ib/gal) (Ib/gal) 1629.0 12.50 8.20 P-Frost 1799.0 12.50 8.70 T3 Sandstone 2305.0 12.50 8.70 K15 Sandstone 2792.0 12.50 8.70 TD Sandstone ~I r~~r 1j-756 cemen[.cfw; OS-052006; LoadCase 1075 Surface ;Version wcstem45_89 Page 3 ''RIGINAL • Client CPAI Well 1J-156TLI String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 2: centralizer placement Top of centralization :1992.0 ft Bottom Cent. MD :2782.0 ft Casing Shoe :2792.0 ft NB of Cent. Used :31 NB of Floating Cent. :0 • ~Ghlulnb~rg~r Centralizer Placement Bottom MD Nbr. Cent. I Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 2712.0 27 3/2 S1104610-10 3/4-6.46 31.3 2012.0 (3/16")B 2792.0 4 2/1 S1104610-10 3/4-6-46 87.1 2792.0 (3/16")B Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) S1104610-10 3/46- 10 3/4 15.874 11.874 No Houma 13.500 708.15 1450.02 46 (3/16")B (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 4 1j-156 cement cfw ; OS -052006 ; Loadcase 1075 Surface ;Version wcstem45_89 ORIGINAL Client CPAI ~~I1 ~~1 Wel I 1 J -156 TLI ~~~! String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 3: fluid description Fluid No: 1 Mud Type : WBM Fluid No: 2 Fluid No: 3 Fluid No: 5 Rheo. Model :BINGHAM At temp. : 65 degF DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water Mud DESIGN Density :9.601b/gal Job volume :240.8 bbl CW100 DESIGN Density :8.321b/gal Job volume :50.0 bbl MUDPUSH II DESIGN Density :10.501b/gal Job volume :50.0 bbl ASL DESIGN Density :10.701b/gal Pv :28.660 cP Ty :16.971bf/100ft2 Gel Strength : (Ibf/100ft2) SLURRY Mix Fluid :20.722 gal/sk Yield :4.45 ft3/sk Porosity :62.3 Job volume :402.4 bbl Quantity :508.24 sk Solid Fraction :37.7 Density :8.321b/gal Base Fluid :20.153 gal/sk DeepCRETE DESIGN Fluid No:6 Density : 12.00 Ib/gal Rheo. Model :BINGHAM Pv :105.064 cP At temp. : 63 degF Ty :11.81 Ibf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid :8.231 gal/sk Job volume :77.7 bbl Dry Density : 199.77 Ib/ft3 Yield :2.47 ft3/sk Quantity :176.48 sk Sack Weight : 94 ib Porosity :44.5 % Solid Fraction :55.5 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Base Fluid :8.131 gal/sk Additives Code Conc. Function D046 0.600 %BWOC ANTIFOAM 6160 0.170 %BWOC Low Temp Dis D186 0.100 gal/sk blend ACCELERATOR tj-156 cement.c(w ; OS-052006; Loadcase 7075 Surface ;Version wcscem45_69 Page 5 ~~~~~~ • ~ Client CPAI Well 1J-156 TLI String 103/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Secti on 4: fluid seauence P~ :15.000 cP Displacement Volume 260.8 bbl Total Volume 840.9 bbl TOC 0.0 ft ~~I r~~r Tv :30.00 Ibf/100ft2 Name Volume (bbl) Ann. Len (ft) Top (ft) Fluid Sequence Density (Ib/gal) Rheology CW100 50.0 0.0 8.32 viscosity:5.000 cP MUDPUSH II 50.0 0.0 10.50 Pv.23.000 cP Tv:30.00 Ibf/100ft2 ASL 402.4 1992.0 0.0 10.70 Pv.28.660 cP Tv:16.97 Ibf/100ft2 DeepCRETE 77.7 800.0 1992.0 12.00 Pv.105.064 cP Tv:11.81 Ibf/100ft2 Water 20.0 2504.0 8.32 viscosity:1.000 cP Mud 240.8 0.0 9.60 Pv.15.000 cP Tv:30.00 Ibf/100ft2 Static Security Checks Frac 7 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 2039 psi at 2712.0 ft Burst 4230 psi at 0.0 ft Csg.Pump out 35 ton Section 5: pumping schedule Name Flow Rate (bbUmin) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 40.0 8.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 50.0 8.3 50.0 80 ASL 7.0 402.4 57.5 402.4 80 DeepCRETE 6.0 77.7 12.9 77.7 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 7.0 231.8 33.1 231.8 80 Mud 3.0 9.0 3.0 240.8 80 Slow & bump plug Total 02:33 840.9 bbl hr:mn D namic Securit Checks Frac 7 psi at 80.0 ft Pore 0 psi at 80.0 ft Collapse 2039 psi at 2712.0 ft Burst 4015 psi at 0.0 ft tj-156 cement.cfw; OS-052006 ; Loadcase 1075 Surface ; Version wcs-cem45_89 Page 6 ~~~~~ ~~ I ~µ ~ ~~ • • Client CPAI Well 1J-156TLI String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface ft O , 0 0 o' O °o' N O O O M- Fluid Sequence _m ~_ N N ~ 3 N N N O a c c Q m Ib/gal 8 12 1 .L-____1____T._1 ---- Hydrostatic i Min. Hydrostatic 1 - Max. Dynamic I I - - Min. Dynamic i --~ Frac I ~. Pore J -i~-~ •-~----~-•----- a A I 1 .~ ?~ I 1 t_.; j1 i I ~ 1i ~~ ~ 1 1 I 1 1 I I 1 L Dynamic Well Security Time (min) 0 c n ~_ d ~ m tY 3 0 LL O Schluma~rg~r o. 2 0 100 200 Time (min) De th = 2792 ft 00 ~ N - ;•-•-----; Annular Velocity i i ~ ---------------•-------~ i i i i i ~` O i i U O~ ~ J ~ ' h 1~ ~I I ' j ` 1 1 ~ h ! i! Q II ~ 1 ~, ~^i 1 ~ 1 Oi:_iJl. _._._._._._ry~t._._'_._._._.y 0 100 200 Time (min) 0 25 50 75 100 125 150 175 Time (min) Page 7 ij-156 cementc(w ; OS-052006 ; Loadcase 1075 Surtace ; Version wcscem45_69 G~IGiNAL • ~~rnr CemCADE Preliminary Job Design 7-5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/5/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 10 3/4", 45.5# casing at 2,792' MD < Top of Tail at 3,650' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 6,863' MD (3,628' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 800' MD above target - (3213' MD annular length). Sperry WP05 Tail Slurry Minimum thickening time: 190 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3213' x 1.25 (25% excess) = 862.7 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 862.7 ft3 + 20.6 ft3 = 883.3 ft3 883.3 ft3/ 2.25 ft3/sk = 392.6 sks Round up to 400 sks BHST = 85°F, Estimated BHCT = 73°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpml Volume (min) Time Ibbll (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 65.0 13.0 25.0 Drop bottom plug 0.0 0.0 5.0 30.0 MUDPUSH II 5.0 75.0 15.0 45.0 DeepCRETE 5.0 157.3 31.5 76.5 Drop top plug 0.0 0.0 5.0 81.5 Water 5.0 20.0 4.0 85.5 Switch to rig 0.0 0.0 5.0 90.5 Mud 6.0 282.4 47.1 137.6 Slow & bump plug 3.0 9.0 3.0 140.6 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: 12.0 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommendation -Tandem Rise Centralizers ~s.~ 2 on shoe track ~s.es 3 per 2 joints across the West Sak .~.~ 1 per joint across the Ugnu °~ ( r tt sw. ;M~ i € ~ r~ Scl~omberger CemCADE*well cementing recommendation for 7-5/8" Intermediate Casing Operator : CPAI Well 1J-156 TLI Country :USA Field West Sak State :Alaska Prepared for :Mike Greener Location Proposal No. : V1 (WP05) Service Point Prudhoe Bay Date Prepared :May 05, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by :Mike Martin Phone (907) 263-4207 E-Mail Address martinl3C~slb.com ~~~ . ~ C ~L 9~V AT E Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of [he actual results that may be achieved and should be used far comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify [he owner or owners of [he well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is notto be inferred. * Mark of Schlumberger • Client CPAI Well 1J-156 TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 1: well description Configuration Stage Rig Type Mud Line Total MD BHST Bit Size ft o- 0 0 ~- 0 0 o- Ugnu B 0 0 o- 0 0 o- 0 0 0 r~ . :Casing Single Land 0.0 ft 6863.0 ft 79 degF 9 7/8 i n Well K-13 • West Sak D - -• West Sak C •• West Sak A.4 • West Sak A3 • West Sak A2 Schlum6~rg~r Lithology Formation Press. 1j-156cemenLCfw;05-052006; Loadcase]581ntermedia[e;Veaionwcstem45_89 Page 2 ORIGINAL (x 100D} psi n ~~ • • Client CPAI ~~Irg~r Well 1J-156TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Previous String MD OD Weight ID (ft) (in) (Ib/ft) (in) 2792.0 10 3/4 45.5 9.950 Landing Collar MD :6783.0 ft Casing/liner Shoe MD :6863.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 6863.0 7 5/8 40.0 29.7 6.875 L-80 4790 6890 BTC MD (ft) Frac. (Ib/gal) Formation Data Pore Name (Ib/gal) Lithology 4152.0 12.50 8.20 Ugnu C Sandstone 4526.0 12.50 8.20 Ugnu B Sandstone 4705.0 12.50 8.20 Ugnu A Sandstone 5035.0 12.50 8.40 K-13 5625.0 12.50 8.40 West Sak D Sandstone 5834.0 12.50 8.40 West Sak C Sandstone 5952.0 12.50 8.40 West Sak B Sandstone 6188.0 12.50 8.40 West Sak A4 Sandstone 6453.0 12.50 8.40 West Sak A3 Sandstone 6863.0 12.50 8.40 West Sak A2 Sandstone Geothermal Tem erature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1629.0 1520.2 30 0.3 2792.0 2168.0 46 1.0 3650.0 2592.3 57 1.3 6863.0 3406.6 79 1.6 1j-756 cemenCCfw;05-052006; Loadcase 7561n[ermediate;Versionwcstem45_89 ~~~~~.~ Page 3 • Client CPAI Well 1J-156 TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Mean OH Diameter :9.875 in Mean Annular Excess :25.0 Mean OH Equivalent Diameter: 10.361 in Total OH Volume :424.6 bbl (including excess) Max. Deviation Angle : 94 deg Max. DLS :15.916 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 80.0 80.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000. 400.0 400.0 2.5 280.0 2.500 500.0 499.7 5.0 280.0 2.500 600.0 599.1 7.5 280.0 2.500 702.1 700.0 10.1 280.0 2.499 800.0 795.9 13.5 280.0 3.502 900.0 892.3 17.0 280.0 3.500 1000.0 987.0 20.5 280.0 3.500 1100.0 1079.6 24.0 280.0 3.500 1200.0 1169.7 27.5 280.0 3.500 1300.0 1256.9 31.0 280.0 3.500 1400.0 1341.0 34.5 280.0 3.500 1500.0 1421.7 38.0 280.0 3.500 1601.9 1500.0 41.5 280.0 3.503 1701.9 1574.8 41.5 280.0 0.000 1800.0 1645.9 45.6 277.4 4.495 1900.0 1713.2 49.7 275.0 4.502 2000.0 1775.0 53.9 273.0 4.501 2100.0 1830.9 58.2 271.1 4.499 2166.3 1864.5 61.0 270.0 4.499 2200.0 1880.8 61.0 270.0 0.000 2300.0 1929.3 61.0 270.0 0.000 2400.0 1977.8 61.0 270.0 0.000 2500.0 2026.3 61.0 270.0 0.000 2600.0 2074.8 61.0 270.0 0.000 2700.0 2123.4 61.0 270.0 0.000 2792.0 2168.0 61.0 270.0 0.000 2800.0 2171.9 61.0 270.0 0.000 2900.0 2220.4 61.0 270.0 0.000 3000.0 2268.9 61.0 270.0 0.000 3016.3 2276.8 61.0 270.0 0.000 3100.0 2317.7 60.5 265.7 -4.503 3200.0 2367.3 60.0 260.6 -4.500 3300.0 2417.4 59.8 255.4 -4.497 3400.0 2467.8 59.8 250.2 -4.503 3500.0 2517.9 60.0 245.0 4.501 3600.0 2567.7 60.4 239.8 4.501 3705.8 2619.5 61.0 234.4 4.495 3800.0 2665.2 61.0 234.4 0.000 3900.0 2713.7 61.0 234.4 0.000 4000.0 2762.2 61.0 234.4 0.000 4100.0 2810.7 61.0 234.4 0.000 4200.0 2859.2 61.0 234.4 0.000 ~rl! r~r ij-156 cementcfw; OS-052006; Loadcase 7581ntermediate;version wcs-cem45_69 • Page 4 • Client CPAI Well 1J-156 TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate MD (ft) Directional Survey Data TVD Deviation Azimuth ft de) (de) Dogleg Sev. (de /100ft) 4300.0 2907.8 61.0 234.4 0.000 4339.8 2927.1 131.0 234.4 0.000 4400.0 2956.1 61.3 231.3 4.507 4500.0 3003.7 61.9 226.2 4.493 4600.0 3050.2 62.7 221.2 4.500 4700.0 3095.3 63.7 216.3 4.499 4800.0 3138.8 64.8 211.5 4.508 4900.0 3180.3 66.1 206.8 4.495 5000.0 3219.6 67.t3 202.1 4.506 5100.0 3256.4 69.2 197.6 4.494 5200.0 3290.6 70.8 193.1 4.501 5300.0 3322.0 72.6 188.8 4.506 5400.0 3350.2 74.5 184.5 4.498 5500.0 3375.3 76.5 180.4 4.501 5525.4 3381.1 77.0 179.3 4.486 5600.0 3397.9 77.0 179.3 0.000 51325.4 3403.13 77.0 179.3 0.000 5637.4 3406.1 78.9 179.3 15.916 5667.4 3411.9 78.9 179.3 0.000 5700.0 3417.6 80.9 179.3 5.993 5750.0 3424.2 83.9 179.3 6.000 5800.0 3428.3 86.9 179.3 13.000 5850.0 3429.7 89.9 179.3 6.000 5867.6 3429.6 90.9 179.3 6.026 5900.0 3428.5 92.9 179.4 5.999 5913.0 3427.8 93.6 179.5 6.007 6000.0 3422.3 93.6 179.5 -0.000 t3100.0 3415.9 93.6 179.5 0.000 6182.5 3410.7 93.6 179.5 0.000 6200.0 3409.7 92.6 179.4 -6.053 6228.4 3408.9 90.9 179.2 -5.986 6300.0 3407.7 90.9 179.2 0.000 6400.0 34013.2 90.9 179.2 0.000 6500.0 3404.6 90.9 179.2 0.000 6600.0 3403.0 90.9 179.2 0.000 6628.4 3402.6 90.9 179.2 0.000 6700.0 3401.5 90.9 179.2 0.000 6728.4 3401.0 90.9 179.2 0.000 6800.0 3402.1 87.3 179.2 -5.002 t3842.0 3404.9 85.2 179.2 -4.999 6863.0 3406.6 85.2 179.2 0.000 ~61rg~r tj-156cemen[.cfw;05-0 5 2006; LoadCase7681ntermediate;Versionwcs~em45_69 Page 5 ~. . • Client CPAI Well 1J-156TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 2: centralizer placement Top of centralization :3650.0 ft Bottom Cent. MD :6853.0 ft Casing Shoe :6863.0 ft NB of Cent. Used :92 NB of Floating Cent. :0 Schlurnb~rg~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 4903.0 31 1/1 7-5/8 TR 76TR 0.0 4885.4 5263.0 0 0/0 0.0 4903.0 6783.0 57 3/2 7-5/8 TR 76TR 0.0 5280.6 6863.0 4 2/1 7-5/8 TR 76TR 92.7 6863.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ib~ 7-5/8 TR 76TR 7 5/8 10.500 9.000 No Weatherford ~'~ 9.875 375.00 3168.00 (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 6 1j-156 cement.cfw; 05-052006; Loadcase 7581ntennediate;version wcstem45_89 ORIGINAL • • Client CPAI Well 1J-156 TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 8.90 Ib/gal Mud Type : WBM Job volume :291.4 bbl CW100 DESIGN Fluid No: 2 Density : 8.32 Ib/gal Job volume :75.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 11.00 Ib/gal Job volume :75.0 bbl Fluid No:4 Rheo. Model : HERSCHEL_B. At temp. : 80 degF DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water ~~Ir~~r DeepCRETE DESIGN Density :12.501b/gal k :8.69E-31bf.s^n/ft2 n :0.833 Ty :O.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) SLURRY Mix Fluid :7.558 gal/sk Job volume :157.3 bbl Yield :2.25 ft3/sk Quantity :392.48 sk Porosity :44.9 % Solid Fraction :55.1 Density : 8.32 Ib/gal Base Fluid :7.418 gal/sk Code Additives Conc. Function D124(0. 31.000 %BWOC Extender 76) D178 24.000 %BWOC SILICA D046 0.600 %BWOC ANTIFOAM B160 0.600 %BWOC Low Temp Dis D167 0.300 %BWOC FLUID LOSS D186 0.140 gal/sk blend ACCELERATOR Water Fluid No:5 Density : 8.331b/gal Job volume :20.0 bbl Page 7 1j-156 cementctw; 05-052006; Loadcase 7691n[e°nediate;version wcscem45_89 E • Client CPAI Well 1J-156TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate ~~~I~lrg~r Section 4: fluid se uence Original fluid Mud 8.90 Ib/gal k : 1.13E-2 Ibf.s^n/ft2 n :0.517 Tv :6.47 Ibf/100ft2 Displacement Volume 311.4 bbl Total Volume 618.7 bbl TOC 3650.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) CW100 75.0 1889.4 46.6 8.32 k:6.68E-31bf.s^n/ft2 n:0.177 Tv:0.001bf/100ft2 MUDPUSH II 75.0 1714.0 1936.0 11.00 k:8.59E-2 Ibf.s^n/ft2 n:0.279 Tv:11.82 Ibf/100ft2 DeepCRETE 157.3 3213.0 3650.0 12.50 k:8.69E-3 Ibf.s^n/ft2 n:0.833 Tv:0.00 ibf/100ft2 Water 20.0 6347.4 8.33 k:6.94E-31bf.s^n/ft2 n:0.281 Tv:0.071bf/100ft2 Mud 291.4 0.0 8.90 k:1.13E-21bf.s^n/ft2 n:0.517 Tv:6.471bf/100ft2 Static Securit Checks Frac 409 psi at 2792.0 ft Pore 75 psi at 2792.0 ft Collapse 4435 psi at 5833.4 ft Burst 6839 psi at 1936.0 ft Csg.Pump out 39 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 65.0 13.0 75.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 5.0 75.0 15.0 75.0 80 DeepCRETE 5.0 157.3 31.5 157.3 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 6.0 282.4 47.1 282.4 80 Mud 3.0 9.0 3.0 291.4 80 Slow & bump plug Total 02:20 618.7 bbl hr:mn D namic Securit Checks Frac 156 psi at 6863.0 ft Pore 42 psi at 2792.0 ft Collapse 4326 psi at 481.1 ft Burst 6348 psi at 2163.8 ft tj-156cement.cfw;05-0 5 2006; Loadcase]581ntermedia[e;Versionwcstem45_89 • Page 8 • Client CPAI Well 1J-156 TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate Section 6: WELLCLEAN II Simulator ft o- 0 o- ~_ o- 0 o- ~_ 0 0 o- 0 0 o- 0 0 0 r~ . ~~o Cement Coverage ID Schlulna~rg~r Risk Mud on the Well 0 z 4040 4500 5000 L s 5500 0 1:4ud 0 FAUDPUSH II 0 tlater ®C~N100 ~ C~eepCRETE i z ~ _ 4p04- L ' ~ aG00 4500- ;, `-, 4500 5000 - ~` r 4 ' ~ ~ .-. 5000 s t 0 5500 - 0 s 5500 0 6000 c . 5000 6500 -~ 5500 3 0 ` o z ~ High ~ Love ~ I.4ediurr~ None tj~156 cement.cfw;05 A52006; LoadCase7581n[ermedia[e; Version wcs-cem45_89 • Page 9 ORIGINAL • • Client CPAI Well 1J-156 TLI String 7-5/8lntermediate District Prudhoe Bay Country USA Loadcase 7581ntermediate ft O ~ 0 0 o- N O 0 o- O O ti• Fluid Sequence d m a C Q Q 8 12 1~ .L.----1--.-7._~ -~-• Hydrostatic i ~- Min. Hydrostatic i ~-- Max. Dynamic - - Min. Dynamic i Frac 1 i - Pore ; -~--~ i i i i _i_..i ,l B 1~~1' ~ ) i i .~._~ i i i l i Dynamic Well Security Time (min) Fluids at 6863 ft r c a a_ d m (Y 3 0 ll C Time (min) S~hl~m6~rger O Calc WHP i O --•-•-•-•- - ~ _, ~~ .-. S 1 N I .~e_'.~..._ _:.....,... a ~ r I I E o~ ~ ~ _.._... Ot._._.__ L._._r~ -._._._._._._.1 0 100 200 Time (min) De th = 6863 ft o ,•---•---; ~ oN -Annular Velocity i i --~ 'v Oii l fl --t L i i ~ M ~ I! 111 1 1n• h ! !! i'1i I C li ~ I! 1 Q ii ! ~! ~~ i Oi~-i-'~_.___._._._r_._._._._._._._.1 0 100 200 Time (min) Page 10 1j-756 cemenLCfw; 05-052006; Loadcase 7581ntermedia[e;version wcs<em45_69 Ib/gal O V r~ 1 O Insulated Conductor ~ Casing, 20", 94#, K55 x ~ 34", 0.312"WTL ~ +/- 80' MD ~~ Q -o v~ ~ ~ ~ ~ ~ ~ .. ~~ c n .. Ui o. o T o " ~ ~ " 3 <' y n a 6a ~R~ 10-3/4", G8#, L-SQ, BTC, R3 ~ a~7 2,792' MD / 2,168' TVD ~~ ~ 41.6 degrees TD 13-3/8" hole Top of Uguu C 4,10U' D'ID / 2,811' TVD ~ Lateral Entry Module #2 (LEM), Baker, with seal bore and ZXP packer (r# x xxx' MU, x,xxx' TVU 1'op of West Sak A ~~ 6,200' MD / 3,519' 1'VD - -~ Lateral Entry Module # I (LEM), Baker, with seal bore and ZXP packer ~ x,xxx' MD, x,xxx' TVD Tubing, 4-'/:" IBTM, Gom LEM to A2. Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer for A2 liner ~ +,042' MD, 3,G30' -f VD 7-5/8", 40#, L-8Q BTCM, R3 Csg ~ 6,863' MD / 3 G28' TVD ~ 86 degree TD 9-5/8" hole ~~- \S C~ I1-156 L2: 6-3/4" D sand lateral TD 12,596' MD / 3,303' TVD Angle 90 degrees I1-156 LI: 6-3/4" "B" sand lateral TD 12,994' hID / 3,381' TVD Angle 90 degrees ~ I1-156: 6-3/4 A2 sand lateral IT MD / 3,637 TVD Angle 90 degrees Wellhead /Tubing Head /Tree, 10-3/4" x 4-''/s", 5,000 ksi Tubing String. 4-1/Y', 12.G #, L-80, IBTM (1) 3.875" UB nipple set +/- 500' (1) Gas Lift Mandrel, CMiCO 4- I /2" x l " Nlodel KB G-2, rr 25 deg, 1,200' MD, 1,169' T VD. (1) Cas LiR Mandrel, CAMCO 4-I/2" x I" Model KBG-2, rCi 70 deg., (+/_ 1 joint above sliding sleeve) - (I) Sliding Sleeve, with 3.812" nipple, ~ 72 deg., (+/_ 1 joint above seals) 156 L2 "D" Sand Window L 5,625' MD / 3,404' TVD 73 degrees "D" Liner, 4-I/2", 11.6#, L80, BTCM, RZ 156 LI"B" Sand Window (~ 5,952' MU / 3,476' TVD 80 degrees ~- "B" Liner, 4-1/2", 11.6#, L80, BTCM, R2 A2 Sand Liner, 4-1/2", l 16#, LBU, BTCM, R2 /. ~1 • • • • SHARON K. ALLSUP-DRAKE 1147 CONOCOPHILLIPS ATO 1530 ~J ` L z~ ~~ 700 G ST. DATE J 56.1551/441 ANCHORAGE AK 99501 ~/' /µ~ / ORDER OFE ~~~ ! ~ ~ / / ~~S~f / 1 OC`~ l~~ ? $~UO.CO / ~ ~ ~ ~~ _ ..~--~ ~ G O.J.. OLLARS LJ o~,,.e~s.~w JPMorganChase ~ j vai~d up To 5000 ~ouars JPMorgan Chase Bank, N.A. Columbus, OH ~~ /~ M~ MEMO -~ -~%~!~?t----- ~---- ---f --------~ --- - ~0441L55L1~:528747~907927~~• L X47 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~ `~ _ ~~'~ PTD# Z.~~. - ~~'7 Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing we[1 (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1!25/06 C:\jody\transmittal_checkl ist ~ ~ 00 N , : „ „ ,: „ , , ~, a~ ° d N Cj, ,, ,: , , N O ~ N. , ~ ~ , : c. - N ~, ~ N v o: , .°, ~ . ~ , o L ~, . o, ~ L ~ ° vi. ~ c. °: `~ w U m > c i ~' a' ~ a, m a, , a~ ar _ ° H; ~ ~ ~ L ~~ ~ g a c ~~ a' O a ~ O: u i, ~~ c' ~ ~ ~ _, M• •a' ~ ~~ ~ O ~ ~~ ~ ~ ~ ~ ~ ~ fG6: ~ ~ ~ , ~ •0~ w , 0 ~ d ~~ ~ d ~~ ~ ~ w~ ~ ~ ~ ~ ~ 0, ~ ~ ~ W. ~ d ~ ~ N ~ ~ , 0 O. i O ~ C, a• ~ ~ O~ ~ Os ~ y, ~ ~ ~ ~, ~, ~ ~ ~~ ~ 4 7. , Q. ~ ~~ ~ ~ ~ ~ i O , ~, ~ C' y, ~ L (N6, ~ ~, ~ a, ~ ~ ~~ 00 ~ O a9 , ~ ~ a ~ ~ _a o ~ ~ 3. a. O, a. L. a ~ ~ o ~ ~ ~ r ~ °, ° m m Q. ~ c, a, c f6 N 3, ~ . w . ~, a , • Q ~ ~ ~ ~ 3. • ~ ~ n ~ ~ ~, ~, y, a`. ~ ~ 2 ~ o, > d a m: o, ~ ~ ~ rn o a m, o, U. ; ~ 4 W ~ ~, ~, N °, ~ (~ ~ ~, ~ ~ ~ '3, ~ Y N ~ ~ f6 a~ 3, ~ 3 a~ ~ T Q ~ ~ Q Z ~ Y rn O ~ m ~ E , o' , , , ' , , a> c a~ ~ w a ~ 3. c y m p. ° O f6 ~ ~ O y ~ ~ ° Z ~ d . Y. , c. ° a d ~ cD, O. C: ' d, ~ o °~ ~ ~ , ~~ ~ ~ ~ ~ O. ~ ° 'L7. o ~ . o ~ M. ~ ~ ~ c Or a. N n ° : : , , : ' O N N N ~ •3, 4 N ~: M ~ r' T tNA' tq, -a~ W Q O ~ J . ~ ~ ~, ~~ N, m~ o S' ~ O. O. 3. c Z ~~ ~ ~ ~ N c, o a~~ ~ i $ ~ ~~ O~ N~ m. °, a~~ L ~ ~ ~ ~ c . a ~ . c. ~ v~ ~ . n~ ~ ~ d .~~ , ~ c. a d o, d ~: c, 3 ~ N x. N O ~ ~~ N, ~ ~ ~ N a ~~ ~ N~ f0~ ~~ ~ d f6~ ~ U• ~ Q C, ~~ N. m Z C9 o m' E. o ~1 d' N' a~ ~ .~ ~, ~ a. w?' o, ' .- ~, ~ E °, ~' N ~, m d a a ~ ° ~ ~ ti, ~ a ~ T w ~ ~ a L, ~ ~ L: Z O~ ~ >~ @ O• O, Y, ~, U ~, ~ N. ~, ~, U. Q. Y, Y ~ -~ -, Q Q O. ~ O1 ~ ~p~ g Q. ~ N' L• _ O• x: O' Z Z W W a : , Q . , , ~, , , . ~ : , W , ~ , N N~ Ub N, N y: VD f/b N~ N~ VA N~ N, N, N, N, N, N, N, Ul, N~ N, N, N: N, N N N~ N. N~ N, N, N, Q, N~ y, N, Q, N, O, O, N~ N~ ~ N, N, Q, tlh N~ N~ N, N, N, N, N~ VD N, N, N, N, f/D N, O, N, N~ (~~ N, N, Q, Q, Q, O T }' }' }' }' }' }~ r' }' }' }' }~ }' } }~ }' }' Z' }' Z' }' Z' Z' }' }' Z' r' }' }' }' }' }' }' Z' }' r' } Z' Z' Z ;, ~ ~ N ~ ° •~ : ~ , : _, ~, ~,, E, 3. , , ~ , O: U, C, ~, ~ U , O. M. ~ ~ ~ ~ ~ ~ ~ y, ~ ~ N. ~ ~ , Of Y ~ ~ ~ ~ ~ ~ ~ ~ c. v ~~ o. Z, ~ a ~ ~ ~ ~ -°~ m. ~ ~ an ~, ~ ~ Z: °: ~ ~ °, `R I fA ~ ~ ~ ~. ~ ~ ~ ~ ~~ N. N. ~, ~ U' ~ ~ Q ~ ~ d, ~ O, ~ ~ O. N. ~ O- _ V ~ i ~ ~ a C~ ~ >~ G~ O, N~ ~ ~ . ~ d ~ f6, ~ U, ~ ~ ~ .Ufy ~ ~ N, N 'C~ ~~ O~ f0. N• 9=, 7. 3, ~ ~ `t~ C' ' O (6 '~ ~ tll f6 C N, ~ ' J W ~ ~ ~ ~ O~ 3~ •_ p, ~ 3 d N, ~ N 3~ U. N N. ~ c, O, ~ ~ d ~ ~O' ~ ~, -NOS N, ~ ~ y, Y U Z a> v` o c: a, Z' o`' o c. a m. a~, °, ~ m' ~ o, c. m c' m. O: N' °' v o, rn ar 0 ' L c y' y' °' a~ ~ °: o of o: .. . ' ' o f0 `~ U .4 ~ a' ~~ o, ~ d. ~ 3 ~ > ~ ~ Y ° Q a N ~, w '~ S ~ °' c' c ° °1, ~, ~ >` cr c ~, ~ O v ' ~ °' c , m '~ ° Q. ~ : ~ m o, ~ O, > °, y ~ , ~ ~ ~~ , ? o > > a m Y o o ~ : ' Y ~ m. ~ ~, ~ ~ 4 ~ o, ~, ~ ~, ~ °~ ~, a, ~~~ ' aai~~ f6~ ~, ~~ ~ ~~~ ~~~ M~ N' N, ~~ ~ ° ~~ ° ud ' 3~' O aci ' m' a~i 3 `o~' ~ o W o a a' c' `~' ~' 'm ' a ' ` m. 3; ~ 3. ~ , .., ~ ~ ~ :4 ~ 'v: ~, o' ° ~: fl. o, N a •Q i ~, ° 0 . o L Z w U 0 a 0, ~ a, °, > c, 4=, : a~ ~ a. a, O _ °, o: ' O. o: a c. v o' N, a. ~ a~ ° ' o, rn c a N, m ~ J J 'p~ d o (6 N N. Q. ~T ' N' N' O: N 3' N T d o ~ G' U' U' ~ O' y~ N O - ' E ' f0' N ~ ' L7S O• t O ~' ° d N w N~ ' O, T c. N ' d _ a y' d d N N. d N~ y, d L, ~, N, w~ ~j ~j Q - O f6• N ~ a ~ C. U. N 3 _ O otj = t U. O, ~: (6 O. O, ~ N ~~ ' ' 4 V). !~, f6 ~~ •C: O, O) fl- f6 f6 ' , f0. ~ O ' O ~, ~ , T a : _, a c ~~ ~: N' O. d v a~ d O m _ ~, 3 c, d d ~ y >; m c_ m ,~ m. °: ~ ~ 3, c, a, ~ ai ° ° c, a, o* m. vi '~ c ~ ° ~ o ~~, O: a~ m ~, o, ~, o, o, o o ~ >, ~ ii U f6' ~' -' ~ m ~, m. ~ c °, n. n, _ a~ w' a~, 'a' N U ~' •N' a a' o .~ ° s. 3: L' v ' n c O ~, ~ a c. ° ~ C ~ ~ O N' ~' m. °, , N' 'p' O. ;, m. m. m. L C, m ' C, ° ' € r , G~ ca 3~ ° ~ f6, O~ O, o, v, U~ - ~ _~ o' m ._ ~ , _ ~ ~ «?, ° , O, a, ~ O, ~y fife -, c, v, • O~ C, N~ cc, rn m; v, N~ c ~•~ Z w c ~ v v v m. ~ $ o ~ , o , y v ~, o, ~- °, m, o. o, - ° m a`. m, ~ ~ u% °r ~, o ~ ° ~ ~, a. ~ J U E' ; a -' - -, ~ > ~, ~, a -, a~: d a' m' H, N H c, ~ a~ ~ ~ ~ d n o Y ~ v ~ N ~ Y > ~ d o: c, °, ° 4 ' ' 4 m ai m ~' U '' o; ~, ~, ~', , ~, m a. co a 'v' ._ ' , ., : O O L: ~ . , °, , a~, m, a~: m, c o, m M ~ • U , c a J ~, m, ~; O, ~, ~ ~ O, a; a; U ~ d a ¢; ~ U: ~: U U U, U, ¢, - a: ~ o m; m U, ~; ~'; ~; a, a, v~, v~, c.~, V ' - ~ W Q 0 G N M_~ t0 (O f~ 00 O O N_ M V ~ CO ~ OD O O ~ N N N N M I to N N N CO n W N N N O O N M M N M V M M_ M ~O CO n M M M M M O M ~ / ""'~ V F U ° ° ° °~ G O ~ m ~ o N_ m ~ o N m o ~ N U GO W ~ ~ n O ~ O r R O G ~ ~ 01 C •N ~ N iA ~ ~ ~ ~ T O N ~ N / O N y • ~ O o ~ E a ~ ° ~~~'''aaa~,~ w ~ a~ U W ~ a Q a N ~ o C . Q ~-- ~ Q cn t Well I-lisiory File APPENDIX Inforrmiation of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infommation of this nature is accunmulated at the end of the file under APPENDIX. No special effort has been made io chronologically organize this category of information. Sperry-Sun Dri'R'S_ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Aug 08 16:53:08 2006 Reel Header Service name .............LISTPE Date .....................06/08/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/08/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 W-0004467716 P. ORTH D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING • Scientific Technical Services Scientific Technical Services 1J-156 500292331100 ConocoPhillips Alaska, Inc. Sperry Drilling Services 08-AUG-06 MWD RUN 3 MWD RUN 4 W-0004467716 W-0004467716 P. ORTH T. GALVIN D. GLADDEN D. GLADDEN 35 11N l0E 2094 2560 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 2769.0 7.625 6962.0 ~lo -O(o~' ~ /y03t1 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. DEPTH. SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-156 WITH API#: 50-029-23311-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8281'MD/3631'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY P$U TOOL CODE START DEPTH STOP DEPTH GR 2735.0 8215.5 FET 2750.0 8222.5 RPD 2750.0 8222.5 RPS 2750.0 8222.5 RPM 2750.0 8222.5 RPX 2750.0 8222.5 ROP 2780.5 8281.0 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 2735.0 2869.0 MWD 3 2869.0 6968.0 MWD 4 6968.0 8281.0 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 Name Service Unit Min Max Mean Nsam DEPT FT 2735 8281 5508 11093 RPD MWD OHMM 1.54 2000 29.7592 10946 RPM MWD OHMM 1.14 2000 19.2443 10946 RPS MWD OHMM 3.68 2000 14.9441 10946 RPX MWD OHMM 0.91 2000 13.2764 10946 FET MWD HOUR 0.23 58.57 1.77268 10946 GR MWD API 20.93 114.94 71.2442 10962 ROP MWD FT/H 0.43 448.81 155.082 11002 First Reading For Entire File..........2735 Last Reading For Entire File...........8281 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 First Last Reading Reading 2735 8281 2750 8222.5 2750 8222.5 2750 8222.5 2750 8222.5 2750 8222.5 2735 8215.5 2780.5 8281 Physical EOF • File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY • for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2735.0 2823.0 FET 2750.0 2814.5 RPX 2750.0 2814.5 RPS 2750.0 2814.5 RPM 2750.0 2814.5 RPD 2750.0 2814.5 ROP 2780.5 2869.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 03-JUL-06 Insite 66.37 Memory 2869.0 2780.0 2869.0 59.5 59.5 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 66259 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: 9.875 2769.0 Native/Spud Mud 9.10 40.0 8.5 100 7.0 3.300 110.0 4.890 72.0 4.500 110.0 3.200 110.0 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 2735 2869 2802 269 2735 2869 RPD MWD020 OHMM 1.54 2000 419.052 130 2750 2814.5 RPM MWD020 OHMM 5.06 1743.45 59.1091 130 2750 2814.5 RPS MWD020 OHMM 7.67 24.86 15.797 130 2750 2814.5 RPX MWD020 OHMM 0.91 23.7 12.2931 130 2750 2814.5 FET MWD020 HOUR 0.51 57.61 29.5562 130 2750 2814.5 GR MWD020 API 26.44 105.29 59.0393 177 2735 2823 ROP MWD020 FT/H 41.91 448.81 235.299 178 2780.5 2869 First Reading For Entire File..........2735 Last Reading For Entire File...........2869 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ............... Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2815.0 6914.0 RPS 2815.0 6914.0 RPX 2815.0 6914.0 RPM 2815.0 6914.0 RPD 2815.0 6914.0 GR 2823.5 6922.0 ROP 2869.5 6968.0 LOG HEADER DATA DATE LOGGED: 06-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6968.0 TOP LOG INTERVAL (FT) 2869.0 BOTTOM LOG INTERVAL (FT) 6968.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 57.7 MAXIMUM ANGLE: 85.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 67.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.300 110.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.860 93.2 MUD FILTRATE AT MT: 4.500 110.0 MUD CAKE AT MT: 3.200 110.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ • Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2815 6968 4891.5 8307 2815 6968 RPD MWD030 OHMM 4.26 1119.97 15.6657 8199 2815 6914 RPM MWD030 OHMM 4.29 990.65 14.1936 8199 2815 6914 RPS MWD030 OHMM 3.68 1330.66 14.0635 8199 2815 6914 RPX MWD030 OHMM 3.42 1345.1 12.6772 8199 2815 6914 FET MWD030 HOUR 0.23 8.42 0.75091 8199 2815 6914 GR MWD030 API 20.93 114.94 70.6475 8198 2823.5 6922 ROP MWD030 FT/H 0.43 432.8 169.239 8198 2869.5 6968 First Reading For Entire File..........2815 Last Reading For Entire File...........6968 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header dat~or each bit run in separate fil'l's. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 6914.5 8222.5 RPX 6914.5 8222.5 RPD 6914.5 8222.5 FET 6914.5 8222.5 RPS 6914.5 8222.5 GR 6922.5 8215.5 ROP 6968.5 8281.0 LOG HEADER DATA DATE LOGGED: 09-JTJL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8281.0 TOP LOG INTERVAL (FT) 6968.0 BOTTOM LOG INTERVAL (FT) 8281.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.3 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6962.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 115.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ................ .0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point.... • ......Undefined • Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6914.5 8281 7597.75 2734 6914.5 .8281 RPD MWD040 OHMM 3.12 2000 54.5755 2617 6914.5 8222.5 RPM MWD040 OHMM 1.14 2000 33.0876 2617 6914.5 8222.5 RPS MWD040 OHMM 4.72 2000 17.6607 2617 6914.5 8222.5 RPX MWD040 OHMM 4.63 2000 15.2028 2617 6914.5 8222.5 FET MWD040 HOUR 0.36 58.57 3.5937 2617 6914.5 8222.5 GR MWD040 API 48.01 110.8 73.9704 2587 6922.5 8215.5 ROP MWD040 FT/H 2.4 267.4 105.449 2626 6968.5 8281 First Reading For Entire File..........6914.5 Last Reading For Entire File...........8281 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................06/08/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services Physical EOF Physical EOF • End Of LIS File