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204-171
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 29, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1E-114 50029232230000 204-171 1R-36 50029230570000 201-227 T40513 T40514 By Gavin Gluyas at 9:47 am, Jun 02, 2025 1E-114 50029232230000 204-171 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2023-01-05_15987_KRU_1E-114_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15897 KRU 1E-114 50-029-23223-00 Injection Profile 05-Jan-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 9:06 am, Jan 10, 2023 204-171 T37428 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.10 09:08:18 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-114 KUPARUK RIV U WSAK 1E-114 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-114 50-029-23223-00-00 204-171-0 W SPT 3478 2041710 1500 635 636 636 636 71 77 78 78 4YRTST P Austin McLeod 6/5/2022 MITIA 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 1E-114 Inspection Date: Tubing OA Packer Depth 1350 1900 1870 1870IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605190959 BBL Pumped:0.5 BBL Returned:0.5 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:50:25 -08'00' =!; —VI,. PROACTIVE DIAGNOSTIC SERVICES, INC. WELL L®G TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Profile 2) Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 pdsa n cho rag e(a)m a mo rvlog. com 31 -Dec -18 1E-114 CD 204171 30318 �EcEwE� FEB 01 2019 1,OGCC 50-029-23223-00 Date: WOI/L"f PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEPMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:N hivesW.g rTempleteFiles\Templates\DiA,ibution\TransmittalSheets\ConowPFullips_Trmsmitdoc • • Pr6 2O4 7 o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, June 7, 2018 4:40 PM To: Regg,James B (DOA); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt Cc: Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; NSK Optimization Engr; Krysinski, !i Marina L Subject: 1E-114i Pilot Defeated on 6/7/18 Jim, The Low Pressure Pilot(LPP) for West Sak Water Injector 1E-114 PTD (204-171, 204-172, 204-173)was defeated because of low wellhead injection pressure due to breakthrough event that requires diagnostics. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." ✓ Please let me know if you have any questions or concerns. Regards, Courtney Gallo / Marina Krysinski West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Cell: (720) 318- 5762LI)a Pager: (907) 659-7000 #497 SCOW JUN L 1 Kea 1E-114 • S Pr/ z®4 17(O Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, April 17, 2018 9:07 AM I / To: Regg,James B (DOA) � 4Y i iV t e' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK Optimization Engr Subject: LPP/SSV Returned to Service on CPAI Well 1E-114 on 4/17/2018 Jim, The low pressure pilot (LPP) on wellE-114(PTD#204-1711204-172,204-173) was returned to service and removed from the "Facility Defeated Safety Device Log" today,4/17/2018, after the well was shut-in following the completion of wellwork. The LPP had been defeated on 4/15/2018 when the well was returned to service to perform wellwork.This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCAMS 1 K c (E—l (4 • • P�� Zo4 i 71 0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, April 15, 2018 5:02 PM 41(b(065 To: Regg, James B (DOA) V Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt; Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK West Sak Prod Engr; NSK Optimization Engr Subject: Defeated LPP/SSV on CPAI Well 1E-114 on 4/15/2018 Jim, The low pressure pilot (LPP) on well 1E-114 (PTD#204-17 204-172,204-173) was defeated today,4/15/2018, after the well was returned to service following we work.The well is currently injecting 1949 BWPD at 76 psi wellhead pressure. The LPP and surface safety valves(SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative ✓ Approval No. CO 4066.001." Please let me know if you have any questions. Stephanie Thomson for Marina KrysinskiSCANNED West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 1 STATE OF ALASKA ALIOA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate El Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ MARCIT GEL MBE 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 204-171 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service 0 6.API Number: Alaska 99510 50-029-23223-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-114 ADL 25651 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 11,857 feet Plugs measured None feet true vertical 3,788 feet Junk measured None feet SEP 11 2017 Effective Depth measured 11,857 feet Packer measured 7414,7732,8569 feet ©(�(�f 1C true vertical 3,788 feet true vertical 3478,3547,3697 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 20 " 108' MD 108 TVD SURFACE 4,168 feet 10 3/4" 4,198' MD 2296 TVD PRODUCTION 8,709 feet 7 5/8" 8,736' MD 3752 TVD LINER 3,287 feet 4 1/2 " 11,856' MD 3788 TVD Tubing(size,grade,measured and true vertical depth) 4.5" L-80 7,446' MD 3,486'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 7,414' MD 3,478'TVD PACKER=ZXP Liner Top Packer 7,732'MD 3,547'TVD PACKER= HRD ZXP Liner Top Packer 8,569' MD 3,697'TVD SSSV = NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED DEC 1 4 2017 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN — — — — Subsequent to operation: — — 558 165psi — 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-231 Contact Name: John Peirce Authorized Name: John Peirce p ' Contact Email: John.W.Peirce@cop.com Authorized Title: Sr.Wells Engineer tt( �vt-, 47/7 j1 Contact Phone: (907)265-6471 Authorized Signature: Date: Form 10 4U4 Revised 4/2017 0 60T/7 V to>1 / f g- RBDNS ��SEP 1 1 201Submit Original Only S • 1E-114 DTTMSTA JOBTYP SUMMARYOPS 8/14/17 PUMPING FULLBORE MARCIT GEL TREATMENT. PUMPED 20 BBLS LINEAR GEL, TRACKING 66 BBLS CROSSLINKED GEL, &ANOTHER 20 BBLS LINEAR GEL DOWN ONLY TBG FOLLOWED BY 95 BBLS DSL DOWN TBG FOR DISPLACEMENT& FREEZE PROTECT(JOB COMPLETE) a KUP 1 E-114 Con©coPhi lips f 4 Well Attribu Max Angle . D TD x, J'rU, Wellbore APIIUWI Field Name Wellbore Status incl(.) MD(ftKB) Act Btm(ftKB) tapcppt,ggp, 500292322300 WEST SAK INJ 95.10 9,632.41 12,607.0 °, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-114.9/7201710;29:04 AM SSSV.NIPPLE Last WO: 31.52 10/26/2004 Verticel schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;222 - f Last Tag Rev Reason:MARCIT JOB see NOTES pproven 9/6/2017 HANGER, I- ar I' Casing Strings '. u V Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread �ti���TR��� SURFACE 103/4 10.050 29.9 4,197.7 2,296.4 40.50 L-80 BTC CONDUCTOR;31 P108.0 I.; l -Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;522.3 WINDOW L1 7.65 6.625 7,778.0 7,790.0 3,559.4 29.70 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WINDOW L2 7 5/8 6.625 7,465.0 7,477.0 3,492.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 5/8 6.875 26.9 8,736.0 3,725.2 29.70 L-80 BTCM SURFACE;29.9-4,197.7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 'j D LINER LEM 41/2 3.958 7,414.1 7,763.2 3,554.0 12.60 L-80 IBT GAS LIFT;4,478.9 ;a'. Liner Details Nominal ID GAS LIFT;7,069.9 0: Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SR 7,414.1 3,478.5 77.13 PACKER ZXP LINER TOP PACKER 4.960 7,433.1 3,482.7 77.29 SBE 109-47 SEAL BORE RECEPTICLE 4.750 SLEEVE-C;7,370.0 7,451.9 3,486.8 77.45 XO BUSHING CROSSOVER BUSHING 3.930 M. 7,457.1 3,488.0 77.50 HANGER LEM ABOVE HOOK HANGER 3.930 LOCATOR;7,418.0 ! ?- 7,463.2 3,489.3 77.50 HANGER LEM INSIDE HOOK HANGER 3.688 SEAL ASSY;7,419.7 i. 7,760.0 3,553.3 78.04 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread B LINER LEM 4 1/2 3.958 7,732.4 8,617.9 3,705.1 12.60 L-80 IBT SLEEVE;7,457.0-, )p 1'I Liner Details WINDOW L2,7,465.0-7,477.0 lir I�I Nominal ID LINER L2;7,4832-11,809.6 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,732.4 3,547.5 77.68 PACKER ZXP LINER TOP PACKER 4.960 EVO PLUG;7,825.0 7,751.4 3,551.5 77.90 SBE 109-47 SEAL BORE RECEPTICLE 4.750 7,770.3 3,555.5 78.21 XO BUSHING CROSSOVER BUSHING 3.930 7,771.7 3,555.8 78.23 SWIVEL BAKER CASING SWIVEL 3.920 INV D LINER LEM;7,414.1-],]63.2 7,778.0 3,557.0 78.34 HANGER 1 LEM ABOVE HOOK HANGER 3.930 i. .: 7,784.1- 3,558.3 78.44 HANGER 2 LEM INSIDE HOOK HANGER 3.688 -- 7,849.7 3,570.8 79.32 NIPPLE CAMCO DB-6 NIPPLE 3.562 7l� 8,614.6 3,704.5 79.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 WINDOW LI;7,778.0-7,790.0 SLEEVE;7,784.1 ;y P 111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread !yi LINER 4112 3.958 8,569.5 11,856.2 3,788.2 12.60 L-80 DWC ® II Liner Details SLOTS;7,802.0-11,243.0 ...�..I Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID(in) II 8,569.5 3,696.6 79.89 PACKER HRD ZXP LINER TOP PACKER 5.500 LINER L1;7,7798-11,808.4I I 8,588.6 3,699.9 79.90 NIPPLE RS PACKOFF SEAL NIPPLE 1958 IPERF;8,188.0-8,193.0 8,591.4 3,700.4 79.89 HANGER FLEXLOCK LINER HANGER 5.500 •-' e; 8,601.2 3,702.1 79.87 SBE 190-47 CASING SEAL BORE EXTENSION 4.750' •..:��71r..• ASI 11,822.9 3,784.8 84.28 BUSHING BAKER DRILLABLE PACKOFF BUSHING 3.958 il Tubing Strings I ' Tubing Description String Ma...ID(in) Top(ORB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection 8 LINER LEM,7,732.4-8,617.9 . TUBING 41/2 3.958 22.2 7,446.31 3,485.6 12.60 L-80 IBTM Completion Details Nominal ID PRODUCTION;26.9-8,7380 Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Com (in) SLOTS;8,781.0-8,803.0 22.2 222 0.00 HANGER VETCO GRAY TUBING HANGER 3.958 522.3 520.9 10.78 NIPPLE CAMCO DB-6 NIPPLE w/NO GO PROFILE 3.875 SLOTS;0,027.0-9,080.0 7,370.0 3,468.6 76.75 SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 11/1/2004 3.810 7,418.0 3,479.4 77.16 LOCATOR BAKER LOCATOR 3.875 7,419.7 3,479.8 77.18 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 SLOTS;9,120.09,450.0 -1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) iTop(ft(ND) Top Incl Top(ftKB) KB) (°) Des Com Run Date ID(in) 7,457.0 3,487.9 77.50 SLEEVE TYPE-II ISOLATION SLEEV IN D-SAND LEM 11/29/2016 2.580 SLOTS,9,5780-9,660.0 s 7,625.0 3,524.5 77.52 EVO PLUG HES EVO PLUG 8/9/2017 0.000 7,784.1 3,558.3 78.44 SLEEVE TYPE 1 ISO SLEEVE SET IN B-LEM INSIDE HOOK 11/29/2013 2.750 SLOTS;9,909.0-10,160.0-;" HANGER-. [1 SLOTS;10,191.0-10,358.0 Perforations&Slots _ Shot SLOTS;10,482.0-10,524.0 Dens Top(ND) Btm(ND) (shots/ SLOTS;10,555.010,597.0 -. "-i Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,188.0 8,193.0 3,630.4 3,631.3 WS A4,1E- 7/23/2012 IPERF Perforations to inject - - 114L1 Crystal Seal in B LINER SLOTS;10,627.0-10,689.0 FAILED! 8,781.0 8,903.0 3,731.4 3,743.8 WS A2,1E- 10/8/2004 40.0 SLOTS Alternating solid/slotted SLOTS;10,700.0-10,742.0 r 114 pipe-0.125"x2.5"@ 4 circumferential adjacent rows,3"centers SLOTS;10,805.011,095.0 .- •-- A- ..-- SLOTS; staggered 18 deg,3'non -slotted ends 9,027.0 9,089.0 3,753.0 3,756.2 WS A2,1E- 10/8/2004 40.0 SLOTS 114 9,120.0 9,450.0 3,757.0 3,751.1 WS A2,1E- 10/8/2004 40.0 SLOTS SLOTS;11,321.0-11,&54.0 r 114 4 9,576.0 9,660.0 3,741.3 3,734.2 WS A2,1E- 10/8/2004 40.0 SLOTS 11= W4 SLOTS;11,716.0-11,789.09,909.0 10,160.0 3,735.8 3,752.0 WS A2,1E- 10/8/2004 40.0 SLOTS 114 LINER;8,589.5-11,856.2 KUP 1E-114 Conoc©Phillips • • Alaska...lii+:. Conocophd8ps 1E-114,917/2017 10:29.04 AM Vertical schematic(actual) HANGER 222 � L Perforations&Slots ................... Ns i 1�leiJ: .au. Shot IN i Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com ""'601'44 CTTOR;I 31.6108. 10,191.0 10,358.0 3,754.0 3,762.8 WS A2,1E- 10/8/2004 40.0 SLOTS 0 1 _ 114 NIPPLE;522.3 10,482.0 10,524.0 3,768.3 3,769.3 WS A2,1E- 10/8/2004 40.0 SLOTS 114 II ll 10,555.0 10,597.0 3,769.6 3,769.3 WS A2,1E- 10/8/2004 40.0 SLOTS SURFACE 29.9-4,197.7-' ` 114 10,627.0 10,669.0 3,769.0 3,768.5 WS A2,1E- 10/8/2004 40.0 SLOTS 114 GAS LIFT;4,476.9 1; 10,700.0 10,742.0 3,767.9 3,766.7 WS A2,1E- 10/8/2004 40.0 SLOTS GAS LIFT;7,069.9 114 10,805.0 11,095.0 3,763.9 3,746.6 WS A2,1E- 10/8/2004 40.0 SLOTS 114 SLEEVE-C;7,370.0 in M � 11 ,321.0 11,654.0 3,748.1 3,769.7 WS A2,1E- 10/8/2004 40.0 SLOTS 114 LOCATOR;7,418.0 . 11,716.0 11,789.0 3,774.6 3,781.5 WS A2,1E- 10/8/2004 40.0 SLOTS SEAL ASSY;7,419.7 - 114 lee Mandrel Inserts St a^i SLEEVE;7,457.0.E i.1 o Top(TVD) Valve Latch Port Size TRO Run WINDOW LZ 7,465.0-7,477.0 '' I N TopftKB ftKB) Make Model OD Sery T T (in) (psi) Run Date Com LINER L2;7,463.2-11,809.6, III IA. ( ) ( (in) Type -Pe !I_ 1� 4,476.9 2,398.5 CAMCO KBG-2 1 GAS LIFT 'DMY BK-5 0.000 0.0 4/3/2005 7 7,069.9 3,389.6 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 4/3/2005 EVO PLUG;7,625.0 la Notes:General&Safety End Date Annotation 10/26/2004 NOTE:TRI-LATERAL WELL 1E-114(A-SAND)1E-114L1(B-SAND)1E-114L2(D-SAND) MI r 2/16/2011 NOTE:View Schematic w/Alaska Schematic9.OREV D LINER LEM;7,414.1-7,763.2 'Mild MIR 7/27/2012 NOTE:PROFILE MODIFICATION-PUMPED 1320 LBS(4MM)CRYSTAL SEAL @ 4200'TARGETING'B'MBE rt 8/14/2017 NOTE:MARCIT Treatment was pumped to D MBE. 1 WINDOW L1:7,778.0-7,780.0` t il I SLEEVE;7,784.1- SLOTS,7,802.0-11,243.0 LINER LI;7,776.8-11,808.4 I I I IPERF;8,188.0-8,193.0 :tui AEA llnir I.lir I 8 LINER LEM,7,732.4-0,617.9 PRODUCTION,26.9-8,738.0 SLOTS;8,781.08,9030 SLOTS;9,027.0-9,089.0 SLOTS;9,120.0-9,450.0 r SLOTS;9,576.0-9,860.0 SLOTS;9,908.0-10,160.0 SLOTS;10,191.0-10,358.0 SLOTS;10,482.0-10,524.0 SLOTS;10,555.0-10,597.0 SLOTS;10,827.0.10,689.0 SLOTS;10,700.0-10,742.0 SLOTS;10,605,611,085.0 4 1 ,I SLOTS;11,321.0-11,654.0 SLOTS;11,718.0-11,789.0 1• 14 LINER;8,589.5-11,856.2 • • SOF ?jj � �,���yy�1s?. THE STATE Alaska Oil and Gas ti ;s ,A ofALASKA Conservation Commission 1, -__-- t i.tx _:_ = 333 West Seventh Avenue I'" - F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 h. ° '�.,� Main: 907.279.1433 'ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer �l NNED . t" ,1 � ` -., ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1E-114 Permit to Drill Number: 204-171 Sundry Number: 317-231 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, °a/8ilt' Cathy 7 Foerster Chair DATED this /2 day of June,2017. RBDMS U(----JUN 1 3 2017 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN' 0 6 2017 APPLICATION FOR SUNDRY APPROVALS ors{cci iq r 7 20 AAC 25.280 `'" OG 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MARCIT GEL MBC 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory ❑ Development ❑ 204-171 ` 3.Address: , 6.API Number: Stratigraphic ❑ Service ❑ P. O. Box 100360,Anchorage,Alaska 99510 50-029-23223-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1E-114 Will planned perforations require a spacing exception? Yes ❑ No El / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651 • 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): 11,857' 3,788' 11857 3788 1480psi NONE 8261 Casing Length Size MD TVD Burst Collapse Conductor 77' 20" 108' 108' Surface 4,168' 103/4 4,198' 2,296' Production 8,709' 7 5/8 8,736' 3,725' Liner 3,297' 4 1/2 11,856' 3,788' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8188-11789 3630-3781 4.500" L-80 7,418' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-ZXP Liner Top Packer 7414 MD,3478 ND PACKER=ZXP Liner Top Packer 7732 MD,3548 ND PACKER=HRD ZXP Liner Top Packer 8570 MD,3697 ND 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service El 14.Estimated Date for 6/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ 0 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: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.S.Peirce@conocophillips.com / / Contact Phone: (907)265-6471 Authorized Signature: y/,/4 W/ — Date: co /co/17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \-7- 23 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 14S .- f 1 t 1'4 Other: Post Initial Injection MIT Req'd? Yes ❑ No er Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /0 — 1"0 RBDMS L.t/ JUN 1 3 2017 APPROVED BY / Approved dtif-ilivo_ I-1_0/,ftit COMMISSIONER THE COMMISSION Date:6 —/2 —[ 7 l A I Submit Form and Form 1 -40�gZevi`d 4/2017 v I y/y,y,-_valid for 12 months from the date of approval. Attachments in Duplicate • 3 KUP a 1E-114 Clon©coPhillips A. . Well Attri bull, Max Angl TD Alaska.Ins Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cc,,,,, h(110, 500292322300 WEST SAK INJ 95.10 9,632.41 12,607.0 ... Comment 825(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-114,5/2320173:47:02 PM SSSV:NIPPLE Last WO: 31.52 10/26/2004 Vertical schematic.(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,22.2 �,..,..� Last Tag: Rev Reason:SET ISO SLV,PULLED pproven 12/5/2016 Mli�",..a�IA DIVERTER 11111:11 1 1:1 Casing Strings "G` J s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread II� CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread Pi ^A SURFACE 10 3/4 10.050 29.9 4,197.7 2,296.4 40.50 L-80 BTC CONDUCTOR;31.0-108.0 IIr I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread NIPPLE;522.3 : .:I WINDOW L1 7.65 6.625 7,778.0 7,790.0 3,559.4 29.70 L-80 BTC-M Casing Description L2 OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread WINDOW 75/8 6.625 7,465.0 7,477.0 3,492.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread l PRODUCTION 75/8 6.875 26.9 8,736.0 3,725.2 29.70 L-80 BTCM SURFACE;29.9-4,197.7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread D LINER LEM 4 1/2 3.958 7,414.1 7,763.2 3,554.0 12.60 L-80 IBT GAS LIFT;4,478.9 Mr Liner Details Nominal ID GAS LIFT;7,088.9 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,414.1 3,478.5 77.13 PACKER ZXP LINER TOP PACKER 4.960 SLEEVE-C;7,370.0 1 7,433.1 3,482.7 77.29 SBE 109-47 SEAL BORE RECEPTICLE 4.750 � � 7,451.9 3,486.8 77.45 XO BUSHING CROSSOVER BUSHING 3.930 7,457.1 3,488.0 77.50 HANGER LEM ABOVE HOOK HANGER 3.930 LOCATOR;7,418.0 7,463.2 3,489.3 77.50 HANGER LEM INSIDE HOOK HANGER 3.688 SEAL ASSY;7,419.7 -s. 7,760.0 3,553.3 78.04 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B LINER LEM 41/2 3.958 7,732.4 8,617.9 3,705.1 12.60 L-80 IBT SLEEVE;7,457.0` 1J l',1., Liner Details �',' WINDOW L2;7,465.0-7,477.0 1 LINER L2;7,463.2-11,809.6 "I' Nominal ID iTop(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) I7,732.4 3,547.5 77.68 PACKER ZXP LINER TOP PACKER 4.960 7,751.4 3,551.5 77.90 SBE 109-47 SEAL BORE RECEPTICLE 4.750 i 3,555.5 78.21 XO BUSHING CROSSOVER BUSHING 3.930 3,555.8 78.23 SWIVEL BAKER CASING SWIVEL 3.920 D LINER LEM;7,414.1-7,763.2 AR- 7,778.0 3,557.0 78.34 HANGER 1 LEM ABOVE HOOK HANGER 3.930 3,558.3 78.44 HANGER 2 LEM INSIDE HOOK HANGER 3.688 r., ,.t' 7,849.7 3,570.8 79.32 NIPPLE CAMCO DB-6 NIPPLE 3.562 WINDOW L7;7,778.0-7,790.0-, ,,:i! 5�j, 8,614.6 3,704.5 79.84 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 SLEEVE;7,784.1 Casing Description00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Len(I...Grade Top Thread LINER 1 4 1/21 3.9581 8,569 .51 INA /Len 3, 788.21 12.601 L-80 IDWC SLOTS;7,802.0-11,243.0 I _ I Liner Details I-_- Nominal ID Top(ftKB) Top(ND)(ft(B) Top Incl(°) Item Des Com (in) LINER L7;7,776.8-11,8178.4 ' ' 8,569.5 3,696.6 79.89 PACKER HRD ZXP LINER TOP PACKER - 5.500 (PERF;8,188.08,193.0 ' I 8,588.6 3,699.9 79.90 NIPPLE RS PACKOFF SEAL NIPPLE 3.958 FISH;8,281.0 8,591.4 3,700.4 79.89 HANGER FLEXLOCK LINER HANGER 5.500 8,601.2 3,702.1 79.87 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 ,.._If u. Milt 11,822.9 3,784.8 84.28 BUSHING BAKER DRILLABLE PACKOFF BUSHING 3.958 ,Ii1( Tubing Strings I r a ,� Tubing Description I String Ma...1 ID(in) 1Top(ftKB) 'Set Depth(ft...1 Set Depth(ND)(...lWt(113/ft) 'Grade 1Top Connection B LINER LEM;7,732.4-8,617.9 :'418111RTUBING Il 4 1/2 3.958 22.2 7,446.3 3,485.6 12.60 L-80 IBTM Completion Details • Nominal ID PRODUCTION;28.8$736.0 4 .... Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) SLOTS;8,781.0-8,903.0 22.2 22.2 0.00 HANGER VETCO GRAY TUBING HANGER 3.958 522.3 520.9 10.78 NIPPLE CAMCO DB-6 NIPPLE w/NO GO PROFILE 3.875 SLOTS;9,027.08.0880 - _ 7,370.0 3,468.6 76.75 SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 11/1/2004 3.810 7,418.0 3,479.4 77.16 LOCATOR BAKER LOCATOR 3.875 7,419.7 3,479.8 77.18 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 SLOTS;9,125.0-9,4500 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) :::: 7,457.0 3,487.9 77.50 SLEEVE TYPE-II ISOLATION SLEEV IN D-SAND LEM 11/29/2016 2.580 SLOTS;5,576.0-9,e60.0 _ 7,784.1 3,558.3 78.44 SLEEVE TYPE 1 ISO SLEEVE SET IN B-LEM INSIDE HOOK 11/29/2013 2.750 HANGER SLOTS;9,90s.o-15.180.0 8,261.0 3,642.8 80.17 FISH 3"BAKER IBP @ 8261'CTMD IN B-LATERAL 10/1/2010 0.000 SLOTS;10,191.0-10,358.0 r Perforations&Slots Shot SLOTS;10,482.0-10,524.0 Dens Top(ND) Btm(ND) (shots/ SLOTS;10,555.0-10,597.0-.4' Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8.188.0 8,193.0 3,630.4 3,631.3 WS A4,1E- 7/23/2012 IPERF Perforations to inject 114L1 Crystal Seal in B LINER SLOTS;10,627.0-10,659.0 t FAILED! 8.781.0 8,903.0 3,731.4 3,743.8 WS A2,1E- 10/8/2004 40.0 SLOTS Alternating solid/slotted SLOTS;10,700.0-10,742.0 1114 pipe-0.125"x2.5"@ 4 circumferential adjacent 3" SLOTS;10,805.0-11,095.0 4 .1,.._ staggered centers 1188 deg,3'non -slotted ends 9,027.0 9,089.0 3,753.0 3,756.2 WS A2,1E- 10/8/2004 40.0 SLOTS 114 9,120.0 9,450.0 3,757.0 3,751.1 WS A2,1E- 10/8/2004 40.0 SLOTS SLOTS;11,321.0-11,654.0 .y r 114 1 i- 9 576 0 9,660.0 3,741.3 3,734.2 WS A2,1E- 10/8/2004 40.0 SLOTS L 114 SLOTS;11,718.0-11,789.8 . 9,909.0 10,160.0 3,735.8 3,752.0 WS A2,1E- 10/8/2004 40.0 SLOTS 114 9.5- LINER;8.5611,856.2- KUP I� • 1E-114 ConocoPhillips AIdbk;3.lrlc. Conoct 84lhps ••• 1E-114,5/23/2017 3:4703 PM VarAcalschematic(actual) HANGER;22.2 �7••�f� 117 ill. Perforations&Slots . 1 I � I Dene ��� � Shot Top(TVD) Btm(TVD) (shots/ Top(RKB) atm(RKB) (RKB) (RKB) Zone Date ft) Type Corn CONDUCTOR;31.0-108.0 I._ ._� 10,191.0 10,358.0 3,754.0 3,762.8 WS A2,1E- 10/8/2004 40.0 SLOTS NIPPLE;522.3 114 ji 10,482.0 10,524.0 3,768.3 3,769.3 WS A2,1E- 10/8/2004 40.0 SLOTS 114 ' I 10,555.0 10,597.0 3,769.6 3,769.3 WS A2,1E- 10/8/2004 40.0 SLOTS • 114 SURFACE;29.9-4,797.7---. • 10,627.0 10,669.0 3,769.0 3,768.5 WS A2,1E- 10/8/2004 40.0 SLOTS 114 GAS LIFT;4,476.9 10,700.0 10,742.0 3,767.9 3,766.7 WS A2,1E- 10/8/2004 40.0 SLOTS GAS LIFT;7,069.9 : 114 10,805.0 11,095.0 3,763.9 3,746.6 WS A2,1E- 10/8/2004 40.0 SLOTS RES 114 SLEEVE-C;7,370.0 IMO 11,321.0 11,321.0 11,654.0 3,748.1 3,769.7 WS A2,1E- 10/8/2004 40.0 SLOTS 114 LOCATOR;7,418.0 11,716.0 11,789.0 3,774.6 3,781.5 WS A2,1E- 10/8/2004 40.0 SLOTS SEAL ASSY;7,419.7 114 Mandrel Inserts St atii SLEEVE;7,457.0, o Top(TVD) Valve Latch Port Size TRO Run WINDOW 12;7,485.0-7,477.0 'I N Top(RKB) (RKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com LINER L2;7,4W 2-11,809.6, 1 4,476.9 2,398.5 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 4/3/2005 2 7,069.9 3,389.6 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 4/3/2005 Notes:General&Safety End Date Annotation 10/26/2004 NOTE:TRI-LATERAL WELL 1E-114(A-SAND)1E-114L1(B-SAND)1E-114L2(D-SAND) D LINER LEM;7,414.1-7,763.2 2/16/2011 NOTE:View Schematic w/Alaska Schematic9.OREV 7/27/2012 NOTE:PROFILE MODIFICATION-PUMPED 1320 LBS(4MM)CRYSTAL SEAL @ 4200'TARGETING'B'MBE t''' 1 WINDOW L1;7,778.0-7,790.0` I, '� SLEEVE;7,784.1 !;I 111 SLOTS;7,802.0-11,243.0 _ LINER L1;7,776.8-11,808.4 i ' (PERF;8,188.0-8,1930 I FISH;8,261.0 :3LY.• al B LINER LEM;7,732.4.8,817.9 PRODUCTION,26.9-8,736.0 SLOTS;8,781.0-8,903.0 SLOTS;9,027.0-9,089.0 SLOTS;9,120.09,450.0 Ti I I 1SLOTS;9,576.0-9,660.0 L I SLOTS;9,909.0-10,160.0-.1. SLOTS;10,191.0-10,358.0 SLOTS;10,482.0-10,524.0 TILL' SLOTS;10,555.0-10,597.0 4 t_ SLOTS;10,827.0-10,889.0 4 ft SLOTS;10,700.0-10,742.0 1 SLOTS;10,805.0-11,095.0 4 SLOTS;11,321.0-11,854.0 i SLOTS;11a16.0-11,78e.0 1 1 LINER;8,589.511,558.2 • Proposal 1E-114L2 to 1E-168L2 D MBE Treatment with MARCIT Gel 1E-114 tri-lateral injector is completed in West Sak A, B, and D sands. This well has 4-1/2", L-80 tubing and 1E-114L2 lateral contains 4-1/2" L-80 slotted liner. A Matrix Bypass Event (MBE) occurred December 2013 in 1E-114 while the B lateral was isolated with an Iso-Sly. An IPROF was run 5/12/15, that indicated the B lateral was isolated. Thus--it was'suspected that a D MBE must have existed. On 7/9/15, a D iverter was set and a D lateral IPROF was logged, which indicated that a D MBE existed at -7475' RKB just below the D LEM. On 11/29/16, the D Diverter was pulled and a D Iso-Sly was set to return 1D-114 BOI to A sand only. On 1/30/17, a Water Flow log was run which verified that 100% of PWI was entereing the A sand lateral. No other wellwork has been performed since this log run. It is now proposed that a fullbore MARCIT Gel job be pumped to seal off 1E-114L2 D MBE at 7475' RKB. A similar MARCIT MBE treatment of 10/13/16 on 1 J-102ontinues to be successful. Proposed Procedure: Coil Tubing: 1) RIH & pull D Iso-Sly from D LEM at 7472' RKB. 2) RIH & pull B Iso-Sly from B LEM at 7770' RKB. 3) RIH & set DB Plug in 3.562" DB Nipple at 7850' RKB. 4) RIH & set B Iso-Sly across B LEM at 7770' RKB. 5) RIH & set D Diverter in D LEM at 7472' RKB. Fullbore Pumping: 6) MIRU MARCIT Gel pumping equipment to perform a fullbore MARCIT Gel job down 4.5" Tubing to the D MBE assuming that the MBE volume is -50 bbls in volume while monitoring the treating pressure response in 1E-168 producer. This treatment assumes the D MBE is 1500' OAL x 6" diameter (-50 bbls), and that near perfect displacement of the Crosslinked Accelerated MARCIT Gel is possible to the MBE. Pump the job as follows: Inject -20 bbls Uncrosslinked Linear Gel (Pre-Flush), followed by -50 bbls of Crosslinked Accelerated Viscosity MARCIT, followed by 20 bbls Linear Gel displacement, followed by 26 bbls Seawater, followed by 68 bbls Diesel to FP to 2400' TVD, followed by Shutdown to complete the full displacement of all Accelerated MARCIT Gel into the D MBE. Leave the well SI for at least 5 days to let the treatment cure. Coil Tubing: 7) RIH with Jet Swirl Nozzle to jet through excess MARCIT Gel left in the D lateral liner to as deep as possible jetting Seawater. POOH & FP with Diesel. RD. 8) Run a post-MBE treatment memory IPROF in D lateral to verify D MBE is sealed. Return 1E-114L2 to PWI service to D sand only to evaluate results of the D MBE treatment prior to treating the B lateral MBE or reopening the A lateral to PWI. JWP 6/5/2017 • KZc( le-114 Pm azo710 Regg, James B (DOA) From: Regg,James B (DOA) (`1 Sent: Thursday, March 16, 2017 4:14 PM (<1(1 Si I �� To: 'NSK West Sak Prod Engr' Subject: RE: LPP/SSV Returned to Service on CPAI well 1E-114 on 03.15.2017 PTD#s should be 2041710, 2041720, and 2041730 Jim Regg Supervisor, Inspections AOGCC CONNED SEP 1 $ ?0 �, 333 W.7th Ave,Suite 100 w�� Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: NSK West Sak Prod Engr[mailto:n1638@conocophillips.com] Sent:Thursday, March 16, 2017 3:23 PM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>; Sullivan, Michael<Michael.Sullivan@conocophillips.com>; NSK Prod Engr Specialist<n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>;Targac, Gary <Gary.Targac@conocophillips.com>; NSK Optimization Engr<n2046@conocophillips.com>; CPF1 DS Operators <n1275@conocophillips.com>; Krysinski, Marina L<Marina.L.Krysinski@conocophillips.com>; CPF1&2 Ops Supt <n2073@conocophillips.com>; Effiong, Michael<Michael.Effiong@conocophillips.com>; Stanley, Scott M <Scott.M.Stanley@conocophillips.com> Subject: LPP/SSV Returned to Service on CPAI well 1E-114 on 03.15.2017 Jim, The low pressure pilot(LPP) on well 1 E-114(PTD#207-171, 207-172 and 207-173)was returned to service and removed from the "Facility Defeated Safety Device Log" on 03/15/2017 after the well was shut-in. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Scott Stanley /Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 r \-9 • ! e v i s � ' N lac10: ' (9 L: ° {-�U OOt ° �' 1rO7NZ (U > rap0mY 0 0 O u > r 1 Y p CO O Vn N i 4_, . _E, 0 t o > rs C Q p Q' Lu r N L o m JaN a5. ' f0 co f0 f6 co t6 y_ -O U O c ', F T co N N O 00 N Z N N N M u 'a (U 0 U °, > -0 N O i O u ;ill � u 70 m O Ct Cf 0 0 Ct 0 0 v CD 0 0 u J J J J J J bn 0 :� O W WWWWW LL LLLLLLLLL +-, a) (1) NTSO J J J J J J 0. > U) CO Q QQQQQ 0) o0a) Z Z Z Z Z Z N t v 0 tit LL LL LL LL LL LL > ID co +CC u.+ > CU C -,_ ----- 4! 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Q C N '; -1 M M N N CO W vCj Z O1 p O .0 ' rl C 0 f6 Q) OCA al ¢ 01 H a` a F° • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,December 28,2016 P.I.Supervisor ISi (Z.(z///(c+ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-114 FROM: Jeff Jones KUPARUK RIV U WSAK 1E-114 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry\S!3 — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1E-114 API Well Number 50-029-23223-00-00 Inspector Name: Jeff Jones Permit Number: 204-171-0 Inspection Date: 12/11/2016 Insp Num: mitJJ161213204525 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-114 - iType Inj W "TVD 3478 Tubing 38 38 38 - 39 - PTD 2041710 - Type Test SPT Test psi 1500 - IA 1200 1800 1780 1780 - Interval 4YRTST P/F P OA 60 60 61 61 Notes: 0.4 barrels diesel pumped. 1 well inspected,no exeptions noted. SCANNED PR 0 5 2017 Wednesday,December 28,2016 Page 1 of 1 • Kieg, c—I14� Z941ZIa Regg, James B (DOA) From: Regg, James B (DOA) <7 Sent: Monday, December 12, 2016 5:04 PM , �a (24(zI I(o To: 'NSK West Sak Prod Engr' Subject: RE: Defeated LPP/SSV on CPAI well 1E-114 PTD#s should be 204-171, 204-172, and 204-173 Jim Regg Supervisor, Inspections AOGCC SCANNED MAY {. 21�nl:-, h 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Friday, December 09, 2016 10:27 PM To: Regg,James B (DOA) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com>; CPF1&2 Ops Supt<n2073@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF1 DS Operators<n1275@conocophillips.com>;Targac, Gary <Gary.Targac@conocophillips.com>; Sullivan, Michael<Michael.Sullivan@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com> Subject: Defeated LPP/SSV on CPAI well 1E-114 Jim, The low pressure pilot(LPP) on West Sak injector 1E-114(PTD#207-171, 207-172 and 207-173) was defeated today, 12/9/2016. The well was brought online on water injection on 11/30/2016, following a long duration shut-in period. It is currently injecting at approximately 450 BWPD at 108 psi. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the well's function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Thank you. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 1 • • Email: n1638conocophillips.com 2 Zoe{- ri > 25g41,ji WELL LOG TRANSMITTAL DATA LOGGED G/ /2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 21 2015 RE: TMD3D Oxygen Activation Log: 1E-114 Run Date: 5/13/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-114 Digital Data in DLIS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-23223-00 TMD3D Oxygen Activation Log (Processed Log) 1 Color Log 50-029-23223-00 SCANNED . ury 2 2015 TMD3D Oxygen Activation Log (Field print) 1 Color Log 50-029-23223-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: P Ft 710 Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] _ /- Sent: Thursday, April 04, 2013 9:07 AM '`� `l 4k it To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Optimization Engr; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E-114, 4/4/13 Jim, The low pressure pilot (LPP) on injector 1E -114 (204 -171,, 204 -172, and 204 -173) was defeated on April. 4, 2013 when the well was returned to injection service being sFiit in on Oct. 18, 2012 to evaluate a breakthrough event. The well was treated in July '12 for an MBE in the B sand to offset producer 1 E -168. The B sand is current y Iso a . kle i-ri fc 10 Pet Current wellhead pressure is 7 psi at an injection rate bf 889 BWPD. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 CeII: (281) 796 -5044 SCANNED JUL 1 0 2013 M 204 (7(o Regg, James B (DOA) From: Patterson, Amanda [ Amanda .Patterson @conocophillips.com] 161 Z3 I Sent: Monday, October 22, 2012 5:35 PM 1 f1 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: 1E-114 AND 1E-102 removed from Safety Defeat Log: 10/22/12 Jim, West Sak injectors 1E -114 (204 -171, 204 -172, and 204 -173) and 1E -102 (204 -231, 204 -232) have been shut -in and removed from the safety defeat log due to breakthrough events in both wells. 1E-114 was shut in on Oct 18 2012 and 1E- 102 was shut in on Oct 22, 2012. The AOGCC will be notified when the injectors return to service. Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. SCANNED APR 0 9 2013 Office: (907) 265 -6782 Cell: (281) 796 -5044 1 • • Kra 1E- �u Regg, James B (DOA) 17P6 X41 -710 From: Patterson, Amanda [ Amanda. Patterson @conocophillips.com] icy/ Sent: Wednesday, October 17, 2012 3:52 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; CPF1 Prod Engr Subject: LPP /SSV defeated on 1E-114 AND 1E-102: 10/17/12 Jim, The low pressure pilots (LPPs) on both injectors 1E-114 (204 -171 04 -172 L1, and 204 -173 L2) and 1E -102 (PTD# 204 - 231,204 -232) were defeated on Oct. 17, 2012 when e we s were returned to injection service after being shut in for ✓ MBE remediation. Current wellhead pressures and injection rates are as follows: 1E -114 Wellhead Pressure: 3 psi Injection rate: 1220 BWPD 1E-102 SCANNED APR 0 9 2O 3 Wellhead Pressure: 256 psi Injection rate: 1021 BWPD The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." / The AOGCC will be notified when the injection pressure of each well has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Amanda Patterson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 265 -6782 Cell: (281) 796 -5044 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r' Rug Perforations r Perf orate r Other r Crystal Seal Treatment Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Stimulate - Other E Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r r' 204 - 171 3. Address: 6. API Number: Stratigraphic " Service P. O. Box 100360, Anchorage, Alaska 99510 50 e 7. Property Designation (Lease Number): 8. Well Name and Number: ADL25651 - 1E - 114 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11857 feet Plugs (measured) None true vertical 3788 feet Junk (measured) 8261 Effective Depth measured 11770 feet Packer (measured) 7414, 7732, 8570 true vertical 3780 feet (true vertucal) 3478, 3548, 3697 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 SURFACE 4197 10.75 4198 2295 PRODUCTION 8736 7.625 8736 3725 LINER 3287 4.5 11856 3788 RECEIVED Perforation depth: Measured depth: slotted liner 8781' 11789' AUG 2 2 2012 True Vertical Depth: 3731' - 3782 r AOGCC Tubing (size, grade, MD, and TVD) 4.5, L - 80, 7446 MD, 3486 TVD Packers & SSSV (type, MD, and TVD) 3 PACKERS - ZXP LINER TOP PACKERS @ 7414, 7734, 8570 MD and 3478, 3548, 3697 TVD NIPPLE - CAMCO DB -6 NIPPLE @ 522 MD and 521 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 7779' Treatment descriptions including volumes used and final pressure: 1320# of 4MM crystal seal 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1693 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL E r Daily Report of Well Operations XXX GSTOR r WINJ r WAG 17 GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -335 Contact John Peirce (a. 265 -6471 Printed Name John Peirce Title Wells Engineer Signature /e4 ' ..r " — Phone: 265 -6471 Date th s.(1.2. RBDMS AUG 2 3, 2012 "�' 4417---- Form 10 -404 Revised 11/2011 14 r. 13 ' 1 v Submit Original Only KUP 1E-114 ConocoPhiHIpS Well Attributes Max Angle & MD TD Alaska, Irk:, Wellborn API /UWI Field Name Well Status In6l ( °) MD (ftKB) Act Btm (ftKB) 500292322300 WESTSAK INJ 95.10 9,632.41 12,607.0 Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date "' SSSV: NIPPLE Last WO: 31.52 10/26/2004 Well Conk' : -1 E -114, 8/18)2012 11 13'.02 AM schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date .-- +rAReera Last Tag: Rev Reason: ADD DIVERTER ninam 8/18/2012 CONDUCTOR. - 31 -108 ^' Casing Strings NIPPLE. 522 ` r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, -- CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K - 55 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd GAS 4.LIFT, 4 SURFACE 103/4 10.050 29.9 4,197.7 2,296.4 40.50 L - 80 BTC 77 7.070 111 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SLEEVE - C, WINDOW L1 7.65 6.625 7,778.0 7,790.0 3,5592 29.70 L - 80 BTC - M 7,370 LOCATOR, Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 7.418 PRODUCTION 75/8 6.875 26.9 8,736.0 3,724.6 29.70 L - 80 BTCM SEAL A ,420 Description f - Set De D String Wt... String String Top Thrd 7,420 9 0... String ID ... To P( RKB 1 Set Depth Pt ( Depth (TVD) 9 9 •• 9 P WINDOW Lz, Casing PRO^ Strin , WINDOW L2 75/8 6.625 7,465.0 7,477.0 3,492.0 D 74E L I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 4 I D LINER LEM 4 1/2 3.958 7,414.1 7,763.2 3,553.9 12.60 L IBT DIVERTER, 7,779 Liner Details WINDOW L1, Top Depth 7,778 -7.790 SLEEVE. 7784 (TVD) Top Intl Nomi... FISH. 8.261 Top (ftKB) (RKB) ( °) Item Description Comment ID (in) B LINER LEM, 7,414.1 3,478.4 77.13 PACKER ZXP LINER TOP PACKER 4.960 732 PRODUCTION, 7,433.1 3,482.7 77.29 SBE 109 SEAL BORE RECEPTICLE 4,750 27 SLOTS, 7,451.9 3,486.8 77.45 XO BUSHING CROSSOVER BUSHING 3.930 8,781 SLOTS, I 7,457.1 3,488.0 77.50 HANGER LEM ABOVE HOOK HANGER 3.930 9.027 -9.089 SLOTS, 9.120 --9450 9.450 y - 7,463.2 3,488.9 77.16 HANGER LEM INSIDE HOOK HANGER 3.688 SLOTS. 7, - 8,6 18 7,802 11.243 C■ 7,760.0 3,553.3 78.04 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 SLOTS Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ...String Wt... String ... String Top Thrd 9,578 -9660 SLOTS, B LINER LEM 1 4 1/2 I 3.958 I 7,732.4 I 8,617.9 I 3,703.6 12.60 I L - 80 IBT 9,909- 10.160 ' SLOTS, Liner Details 10,191 - 10.358 Top Depth SLOTS, 10,482 -18524 (TVD) Top Inc! Nonni... SLOTS, � Top (ftKB) MB) ( °) Item Description Comment ID (in) 10,555 10.597 i 7,732.4 3,547.5 77.58 PACKER ZXP LINER TOP PACKER 4.960 SL. 10,627 - 10OTS.689 7,751.4 3,551.5 77.90 SBE 109 SEAL BORE RECEPTICLE 4.750 SLOTS, 10,700 10.742 I s Emil r 7,770.3 3,555.3 78.21 XO BUSHING CROSSOVER BUSHING 3.930 SLOTS, 10,805 - 11.095 ' 7,771.7 3,555.6 78.23 SWIVEL BAKER CASING SWIVEL 3.920 SLOTS. 11,321 - 11.654 - 7,778.0 3,556.8 78.34 HANGER 1 LEM ABOVE HOOK HANGER 3.930 SLOTS, 11,716-11789 ER R 11, 7,784.1 3,558.0 78.44 HANGER 2 LEM INSIDE HOOK HANGER 3.686 LINER 7,777-11,808 IN ERL2, , I N 7,849.7 3,570.8 79.46 NIPPLE CAMCO DB-6 NIPPLE 3.652 LINER 7'483 11'810 8,614.6 3,702.8 78.09 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 i. ■1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd - LINER J 41/2 3.958 I 8,569.5 I 11,856.2 3,788.2 12.60 L -80 DWC II Liner Details Top Depth >s (ND) Top Intl Norm.. Top (ftKB) M (°) hem Description Comment ID (In) I 8' 8,569.5 3,696.6 79.89 PACKER HRD ZXP LINER TOP PACKER 5.500 8,588.6 3,696.4 77.37 NIPPLE RS PACKOFF SEAL NIPPLE 3.958 roc -I 8,591.4 3,697.1 77.45 HANGER FLEXLOCK LINER HANGER 5.500 ti ,_' 8,601.2 3,699.6 77.72 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 t ' 11,822.9 3,784.8 84.28 BUSHING BAKER DRILLABLE PACKOFF BUSHING 3.958 ■I Tubing Strings �I L. Tubing Description String 0... String ID ...Top (ftKB) S Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING I 41/2 3.958 I 22.2 ISO 7.446.3 3.485.6 12.60 L -80 I IBTM Completion Details Top Depth (ND) Top Intl Nomi... Top (ftKB) (ftKB) ( °) hem Description Comment ID (in) 22.2 222 -0.32 HANGER VETCO GRAY TUBING HANGER 3.958 522.3 521.0 11.92 NIPPLE CAMCO DB-6 NIPPLE w /NO GO PROFILE 3.875 7,370.0 3,468.6 76.75 SLEEVE -C BAKER CMU SLIDING SLEEVE - CLOSED 11 /1/2004 3.810 7,418.0 3,479.3 77.16 LOCATOR BAKER LOCATOR 3.875 7,419.7 3,479.7 77.18 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Intl ' t Top (RKB) (RKB) P1 Description Comment Run Date ID (in) - { 7,779 3,557.0 78.35 DIVERTER 7/27/2012 7,784 3,558.0 78.44 SLEEVE TYPE 1 ISO SLEEVE SET IN B -LEM 5/18/2011 1.860 8,261 3,642.8 80.08 FISH 3" BAKER IBP @ 8261' CTMD IN B- LATERAL 10/1/2010 0.000 ! 1 Mandrel Details I IN Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (RKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 4,476.9 2,398.3 70.08 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 4/3/2005 9 2 7,069.9 3,389.5 71.87 CAMCO KBG-2 1 GAS LIFT DMY BK -5 0.000 0.0 4/3/2005 LINER, 8,570 - 1106 TD (1E-114), 12,607 KUP 1E -114 Conoc Phillips ;�( Alaska. Inc, , Coot, v a W KB-Grd (ft) Rig Release Date ••• 31.52 10/26/2004 Well Conflg: -1 E- 114,8118!101211:13 02 AM --- _..___ Schematic --deal CONDUCTOR, �� 31-108 - Perforations & Slots NIPPLE, 522 ` r Shot SURFACE, MI • I • P. Top (TVD) Btm (TVD) Dens Top (ft)(B) Btm (88(8) (KM) (ftKB) Zone Date (sh... Type Comment 4.477 8,781 8,903 3,731.4 3,742.4 WS A2, 1E - 114 10/8/2004 40.0 SLOTS Alternating solid/slotted pipe - GAS LIFT, 7,070 0.125"x2.5" @ 4 circumferential SL EEVE - adjacent rows, 3" centers staggered 7.370 :; 18 deg, 3' non - slotted ends LOCATOR, 1 7.418 SEAL ASSV, 9,027 9,089 3,752.0 3,758,5 WS A2, 1E - 114 10/8/2004 40.0 SLOTS 7,420 WINDOW L2, 9,120 9,450 3,757.8 3,751,0 WS A2, 1E - 114 10/8/2004 40.0 SLOTS 7.485 - 7,477 D LINER LEM. ' 9,576 9,660 3,741.3 3,736.2 WS A2, 1E - 114 10/8/2004 40,0 SLOTS 7.414 - 7.763 DIVERTER. 9,909 10,160 3,735.8 3,751.9 WS A2, 1E - 114 10/8/2004 40,0 SLOTS 7.779 WINDGw,790 u, _^ 10,191 10,358 3,754,0 3,762.8 WS A2, 1E - 114 10/8/2004 40.0 SLOTS 7,778 - ] SLEEVE, 7.784 I 10,482 10,524 3,768.3 3,768.9 WS A2, 1E -114 10/8/2004 40,0 SLOTS F NER L 261 ' I B LINER LEM. 10,555 10,597 3,769,5 3,768.4 WS A2, 1E -114 10/8/2004 40.0 SLOTS 7,732 - 8,818 am PRODUCTION, A" 10,627 10,669 3,768.8 3,768.5 WS A2, 1E - 114 10/8/2004 40.0 SLOTS 27 - 8,736 Mg: SLOTS, 10,700 10,742 3,767.7 3,766.7 WS A2, 1E - 114 10/8/2004 40,0 SLOTS 8.781-,903 ,. SLOTS, a1� ;: 10,805 11,095 3,764.1 3,746.7 WS A2, 1E - 114 10/8/2004 40.0 SLOTS 9,027 - 9,089 SLOTS, ; 11,321 11,654 3,750.7 3,769.7 WS A2, 1E - 114 10/8/2004 40.0 SLOTS 9,120 -9,450 =F.;= 7,802 - 11,243 SLOTS, 11,716 11,789 3,774.3 3,781.5 WS A2, 1E - 114 10/8/2004 40.0 SLOTS SLOTS. 9,578 -9.860 t = Notes: General & Safety SLOTS, End Date Annotation 9,909 L. 10/26/2004 NOTE: TRI LATERAL WELL 1E - 114 (A - SAND) 1E - 114L1 (B 1E - 114L2 (D - SAND) 10,191 - 10,358 SLOTS. .. 2/16/2011 NOTE: View Schematic w/ Alaska Schematic9.OREV 10.482 - 10,524 ••� SLOTS ' 10,555-10.597 SLOTS, 10,827 -1 SLOTS I - . 10,700 - 10,742 1 - e SLOTS. 10,805-11,095 SLOTS. 11,321 - 11,654 SLOTS 11.7- 11,708 LINER LI, ],7778 LINER 2 7.483-11,810 k 14 t , li I . ;_r 1 my LINER. 8.570 - 11,856 TO (1E-114), 12,807 1E-114 and 1E-114L1 Crystal Seal Treatment DATE SUMMARY 6/3/12 PERFORMED FLUFF AND STUFF TO 11,855' CTMD. HIT HARD TAG. WASHED ACROSS "LEMS" AND "GLMS" AT 30 FEET PER MINUTE. FREEZE PROTECTED TO 2500' TVD. JOB COMPLETE. BLOW DOWN POP OFF AND SECURE WELL. JOB IN PROGRESS. 6/4/12 SET 2.13" OD IBP AT 8500' IN THE A- LATERAL. RUNNING TOOL SHEARED AT 2850 PSI. TAGGED IBP AT 8500.7' CTMD. SET DOWN 2000 POUNDS CONFIRMED PLUG SET. POOH JOB IN PROGRESS. 6/6/12 RIH TO PULL ISO SLEEVE AT 7780' CTMD, 15 JARLICKS AND IT CAME FREE, RIH TO PULL IBP IN "B" LATERAL, UNABLE TO ENTER THE "B" LATERAL WITHOUT A DIVERTER AFTER MULTIPLE ATTEMPTS, POOH, F/P CT AND TUBING, JOB IN PROGRESS 6/7/12 RIH AND SET B LATERAL DIVERTER AT 7798' CTMD, RIH AND SET TYPE 2 ISOLATION SLEEVE FOR THE D LATERAL AT 7479' CTMD, RIH LATCHED INTO IBP AT 8262' CTMD, PULLED IBP 3' UPHOLE, UNABLE TO GET DOWN MOVEMENT, F/P CT AND TUBING WHILE POOH, JOB IN PROGRESS 6/8/12 PERFORMED BOP TEST, RIH WITH FISHING BHA #1, UNABLE TO MAKE IT THROUGH THE B LEM DIVERTER, POOH AND DROP WT BARS AND INTINSIFIER, RIH AND LATCHED INTO THE IBP AT 8248' CTMD, 28 JARLICKS UP /10 JARLICKS DOWN WITH NO INDICATION OF MOVEMENT FROM THE IBP, PUMP OFF, F/P CT AND TUBING WHILE POOH, JOB IN PROGRESS 7/23/12 PERFORATED LINER FROM 8188' TO 8193' CTMD. UNABLE TO SHIFT OPEN CIRC SUB. PULLED OUT OF HOLE TO SURFACE. RECOVERED BALL IN REEL SWIVEL ON SURFACE. WELL FREEZE PROTECTED. JOB IN PROGRESS. 7/24/12 ATTEMPTED TO PUMP CRYSTAL SEAL. UNABLE TO PENETRATE THROUGH DIVERTER 7778' . DECIDED TO RESET MECHANICAL ZONAL MODIFICATIONS. PERFORMED BOPE TEST WHILE WAITING ON BOT. PULLED ISOLATION SLEEVE. WELL LEFT FREEZE PROTECTED. JOB IN PROGRESS. 7/25/12 RESET DIVERTER IN B -LEM AT 7797.5' CTMD. ATTEMPTED TO DRIFT WITH WAX NOZZLE BHA. MADE SEVERAL ATTEMPTS TO PASS THROUGH DIVERTER WITHOUT SUCCESS. CHANGED OUT BHA AND ATTEMPTED TO PASS THROUGH DIVERTER MULTIPLE TIMES WITHOUT SUCCESS. WELL FREEZE PROTECTED. JOB IN PROGRESS. 7/26/12 PULLED DIVERTER FROM B -LEM AT 7778'. ATTEMTPED TO ENTER ORIENTER WITH 1.5 DEGREE BENT SUB INTO B -LEM WITHOUT SUCCESS. RAN NEW TYPE 1 DIVERTER (2.75" ID) AND SET IN B -LEM AT 7796' CTMD. WELL FREEZE PROTECTED. JOB IN PROGRESS. 7/27/12 SET DIVERTER AT 7779' CTMD. MADE SEVERAL ATTEMPTS TO ENTER LEM WITHOUT SUCCESS. PUMPED 1320 POUNDS OF 4 MM MESH CRYSTAL SEAL. PUH TO SAFETY AT 4200' AND SQUEEZED 8 BBLS INTO MBE. WELL FREEZE PROTECTED ' • • EL SMIE OT ALASKA SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 t r (. ( Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -114 Sundry Number: 311 -335 �y y l�` L Dear Mr. Peirce:'.. ' Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4/ Daniel T. Seamount, Jr. Chair DATED this 2 day of November, 2011. Encl. ATE OF ALASKA I RE i EIV ALASKA OIL AN S CONSERVATION COMMISSION � APPLICATION OR SUNDRY APPROVALSwst' NOV 0 2011 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell ""'" Change ARp F og f Suspend r Rug Perforations r Perforate " Pull Tubing ®` Alaska i n "mmsss,oi Operational Shutdow n r Re -enter Susp. Well "' Stimulate r Alter casing fl Other: Crystal Seal TABtfffaTrdq ; 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204 - 171 3. Address: Stratigraphic r Service ry` 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23223 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No P 1E -114 , 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651 - Kuparuk River Field / West Sak Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11857 3788 - 11770' 3780' 8261' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108 20 108' 108' SURFACE 4197 10.75 4198' 2295' INTERMEDIATE 8736 7.625 8736' 3725' LINER 3287 4.5 11856' 3788' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner 8781 - 11789 3731 - 3782 4.5 L - 7446 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - ZXP LINER TOP PACKER MD= 7414 TVD= 3478 PACKER - ZXP LINER TOP PACKER MD= 7732 TVD= 3548 PACKER - HRD ZXP LINER TOP PACKER MD= 8570 TVD= 3697 NIPPLE - CAMCO DB -6 NIPPLE MD= 522 TVD= 521 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service ]r�` ` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/11/2011 Oil r Gas E WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG i - Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature d'i '1 4. ' .... Phone: 265 -6471 Date la /3 Ili I. Commission Use Only Sundry Number: I 1-33 ✓ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test I"` Location Clearance r Other: Subsequent Form Required: /b "" 4 7 J APPROVED BY �� (2. � � I Approved by: COMMISSIONER THE COMMISSION Date: Form 10 -403 i 1S0 NOV 0 3 a , , I / /l z./( Submit in Duplicate 11/4.1' i � JP 0 1 E -114 Iv ( D // � Max Angle & MD T ����� 1 „ ; ._ Well Attributes .�° � �, i, Wellbore APIIU WI Feld Name Well Status Incl (`) MD K8) Act Btm (ftKB) Cacrtrc*�i710hps 500292322300 WEST SAK _ _JINJ 95.10 1 _ 9,632.41 12607.0 I g, - 5 ,/A201'1 ".: 3725 AM - SSSVo � H2S 'Date !Annotation End Date KB-G 31.52 -Big 10/26/2004 m ,vye{_C M 1 Annotation [Depth ftKB End Date Annotation Last Mod ... End Date HANGER, 22 Last Tag: Rev Reason Pull Type 11 Iso, Set Type I Iso 'Imam 5/21/2011 CONDUCTOR, ` --=.,.. _.... 31-108 = Casin • Shin • S NIPPLE, 522 I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd suRFAGE,_ 4i1 iI g.,, CONDUCTOR 20 19.124 31.0 108.0 108.0 94.00 K - 55 WELDED c ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f Set Depth (TVD) ... String Wt... String ... String Top Thrd 4.d '+ GAS LIFT, SURFACE 10 3/4 10.050 29 9 4,197.7 2296.4 40.50 L - 80 BTC __..� -._ _ 7,070 I Casing Description String 0... String ID ... Top MKS) Set Depth (f Set Depth (TVD) ... String Wt... String ... String Top Thrd SLEEVE WINDOW Lt 7 65 6.625 7,778.0 7790 0 3,559.2 29.70 L BTC - M 7,370 LOCATOR, , Casing Description String 0... String ID ... Top NOON Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd 7,ne - --- PRODUCTION 75/8 6.875 26.9 8736.0 3,724.6 29.70 1 BTCM SEAL A,42. Coo Description String O ... String ID... To (fIKB) Set De f Set De String Wt.. String String To Thrd 1.42, I s p tion g p Depth ( vin (TVD) ._ g e ... p WINDOW 12, WINDOW L2 7 5/8 6.625 7,465.0 7,477.0 3,492.0 7,465 -7.477 . -_- .�� -. --- O LINER LEM, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 7,414 - 7,763 , D LINER LEM 4 1/2 3 958 7,414.1 7,763.2 3,553 9 12.60 L-80 IBT w� Ibw 790 Liner Details FISH, 8,261 To , D /r e , pth B LINER LEM, (ND) Top Intl 7,732 -6,616 �. (ftKB) ND ( "in) PRODUCTION, Top (ftKB) 1 Xan Description Cannent 27 i' 7,414.1 3,478.4 77.13 PACKER ZXP UNER TOP PACKER 4.960 8,781 6,903 SLOrs, 7,433.1 3,482.7 77.29 SBE 109 SEAL BORE RECEPTICLE 4.750 9.027 - 9.089 TD 'S. -- - . 7,451.9 3,486.8 77.45 XO BUSHING CROSSOVER BUSHING 3.930 9,120 - 9,450 7th " 7,457.1 3,488.0 77.50 HANGER LEM ABOVE HOOK HANGER 3.930 7,802 SLOTS, FY I: . __. ° - - SLOTS I - . .- 7,463 -2 3,488.9 77.16 HANGER LEM INSIDE HOOK HANGER 3.688 9.578 -9,660 v 6-6,15 y 7,760.0 3553.3 7804 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 9,909 - 10,160 - SLOTS - Casing Description String 0... String ID ... Top (flK8) Set Depth (f... Set Depth (ND) String Wt... S tring ... String Top Thrd 10,191 10,356 B LINER LEM 41,2 3.958 7,7324 (_86179 I 3,7036 12.60 1 L - 80 IBT SLOTS, T 10,482- 10,524 Liner Details SLOTS, Top Depth 10,555.10,591 D) Top In SLOTS. I •• - (N op tl Nami... 10,627 - 10,669 Top MKS) (ftKB) (1 Nem Description Comment ID (in) 10,700 SLOTS, 4 I 7,732.4 3,547.5 77.58 PACKER ZXP LINER TOP PACKER 6.230 SLOTS, 7,751.4 3,551.5 77.90 SBE 109-47 SEAL BORE RECEPTICLE 4.750 10,805- 11,095 SLOTS. .-- 1121 I r 7,770.3 3,555.3 78.21 XO BUSHING CROSSOVER BUSHING 4.500 SLOTS. 11716 - 11189 7 3 ,555.6 78.23 SWIVEL BAKE CASING SWIVEL 3.960 LINER Lt, 7.777 , , 7,778.0 3,556.8 78.34 HANGER LEM ABOVE HOOK HANGER 3.930 LINER L2, 7,463 113 ,8181 0 7,784 3,558.0 78.44 SLEEVE TYPE I ISO SLEEVE 2.590 7,849.7 3,570.8 79.46 NIPPLE CAMCO DB -6 NIPPLE 3.980 I - - ft 8,614.6 3,702.8 78.09 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 --- Casing Description String 0... !String ID ..Top (ftKB) (Set Depth (f !Set Depth (ND) ... String ng Wl... String . String Top Thrd LINER 4 12 3958 8,569.5 11,856.2 3,788.2 1260 L-80 DWC Liner Details I Top Depth (NO/ Top Icl Nomi... Top (FMB) (flK ( ° ) Item Description Commen ID (in) 8,569.5 3,696.6 79.89 PACKER HRD ZXP LINER TOP PACKER 5.500 c - 8,588.6 3,696.4 77.37 NIPPLE RS PACKOFF SEAL NIPPLE 3.958 8,591.4 3,697.1 77.45 HANGER FLEXLOCK LINER HANGER 5.500 II r 1 8,601.2 3,699.6 77.72 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 11 822.9 3,784 8 84 28 BUSHING - I BAKER DRILLABLE PACKOFF BUSHING _ 3.958 Tubing Strings I II Tubing Description String 0... String ID ...Top (ftKB) Set Depth (L.. Set Depth (ND) .Str Wt.. String ... String Top Thrd TUBING 41)2 3.958 I 222 I 7,446.3 I 3,485.6 12.60 , L -80 IBTM Completion Details Top Depth ' A * °° (ND) Top 1001 Nomi... - Top (ftKB) ( _ () Item Description _ C omment - _ ID (in) I . 4 22.2 22 2 0 32 HANGER VETCO GRAY TUBING HANGER 4.500 522.3 5 0 11 92 NIPPLE CAMCO DB-6 NIPPL 3.875 1 h 7,370.0 3,468.6 76.75 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED (1/1 /2004 3.810 7.419.7 i 479 7 77 16 LOCATOR BAKER LOCATOR 3.875 . 7,418.0 , 77 18 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.875 Ot her In Hole (Wireline retrievable plugs, valves,,pum s fish, etc.)_ o t .v. ° Top Depth _._ -_ ...... -,. .....�. (TVD) Top In i I I Top (ftKB) (ftKB) y) Description Comment Run Date ID (in) M" 8,261 3,642.8 80.08 FISH 3" BAKER IBP @ 8261' CTMD IN B- LATERAL 10/1/2010 0.000 Mandrel Details : ,i i : _,r -;ii , , e.,.,- rn �,*� X , -n Si Top Depth Top Port (TED) Ind - �� � OD Valve Latch Size TRO Run stn Top( (f(KB) (1 _ Mahe Modet (In) Sere TIM TIM. (In) ( an., p Run Date C. - • 4,476.9 2,398.3 70.08 CAMCO KBG-2 1 GAS UFT DMY BKS 0.000 0.0 4/3/2005 i le gig.. 7,069.9 3,389.5 71.87 CAMCO KBG-2 1 GAS UFT DMY BKS 0.000 0.0 4/3/2005 9 LINER, 8,570 - 11,856 \ TO (1E-114), 12,807 , Co� lip►s . SP • 1E -114 ,1r. - - KB.Grd (ft) - Rig Release Date ••• 31.52 10/26/2004 Jtiw,�uc:,Fauial- -- HANGER, 22 CONDUCTOR,_ - 31 -108 =` ' Perforations & Slots NIPPLE, 522- - 11 y Shot SURFACE, Dens z e Date (. 1 Comment 4 > _ �_ 477_ cAS LIFT 8,781 8,903 3,731.4 3,742.4 WSA2, 1 E -114 10/8/2004 40.0 SLOTS Alternating g solili d /sloped pipe - 7,070 0.125'7(2.5" @ 4 circumferential SLEEVE C, 1 I adjacent rows, 3" centers staggered I 7,370 LOCATOR. 18 deg, 3' non - slotted ends SEAL 7.418 V _:' s 9,027 9,089 3,752.0 3,758.5 WSA2, 1E - 114 10/8/2004 40.0 SLOTS 7,420 1 - 9,450 _ WINDOW L2, 9,120 3,757.8 3,751.0 WS 1E - 114 10/8/2004 40.0 SLOTS 7,465-7,477 I INER LEM, 1 D : 9,576 9,660 3,741.3 3,7362 WSA2, 1E - 114 10/8/2004 40.0 SLOTS 7,414 - 7,763 'I; WINDOWL1, ' , 9,909 10,160 3,735.8 3,751.9 WS A2, 1E - 114 10/8/2004 40.0 SLOTS 7,778 - 7,790 " FISH, 8,261 - 1 F , 10,191 10,358 3,754.0 3,762.8 WSA2, 1E -114 10/8/2004 40.0 SLOTS JIM B LINER LEM, �: - - 7.71z 6s1e;;, 10,482 10,524 3,768.3 3,768.9 WSA2, 1E - 114 10/8/2004 40.0 SLOTS PRODUCTION, 'I , 27- TS 6.716, . ' ma . y` _ 10,555 10,597 3,769.5 3,768.4 WSA2, 1E - 114 10/8/2004 40.0 SLOTS SLO _. ___ 8.781-8.903 SLOTS, 10,627 10,669 3,768.8 3,768.5 WSA2, 1E -114 10/8/2004 40.0 SLOTS 9,027 - 9,089 ' AMC 10,700 10,742 3,767.7 3,766.7 WSA2, 1E -114 10/8/2004 40.0 SLOTS SLOTS. 9,120 - 9,450. aAM: 10,805 11,095 3,764.1 3,746.7 WSA2, 1E -114 10/8/2004 40.0 SLOTS 11 SLOTS, 7,802 1 t .:; � _11,321 11,654 3,750.7 3,769.7 WSA2, 1E -114 10/8/2004 40.0 SLOTS .. -.- 9,6,76-SL9,660 _ _ I 11,716 11./85 3 774 3 3,781.5 WSA2 1E-114 10/8/2004 40 0 SLOTS OTS _._ 1' - -_ 9.90&10.160 .r _. -__ _... SLOTS, Notes: General & Safety 10,191-10,358 "'' - - End Date Annotation SLOTS, 10/26/2004 NOTE' TRI- LATERAL WELL 1E -114 (A-SAND) 1E -114L1 (B -SAND) 1E -11412 (D -SAND) SLOTS. I - _ 10,555 - 10,597 - - 2/16/6/ 2011 11 NOTE View Schematic w/ Alaska Schematic9.0 10,627 - 10,669 SLOTS, 2 ,... 10,700-10,742 SLOTS, LO 10,805-11.095 SLOTS. 11,321-11,654 LO SLOTS, -.` �- -. -. 11,716 - 11,789 _ -_ - ........_. _.. - LINER LI, 7,777 - 11,808 LINER L2, 7,463-11,810 LINER 1 - N r�al i I ,I it e' III -1 , ,1 i t .... . Hi2 1 .. 1 , -I_ F.,t, 1 1 ,......., , 1 , ; ; LINER, 8,570 - 11,856 \_ TD (1E-114), 12,607 + • s i 1E-114L1 to 1E-168L1 MBE Treatment A matrix bypass event (MBE) occurred 3/20/06 in 1E-114L1 with breakthrough to 1E-168L1 ✓ producer. A 4/12/06 (PROF in 1E-114L1 found a 'heel' MBE at 8690' RKB behind 4.5" liner. Most PWI appears to exiting the slotted liner at this MBE. We plan to seal the MBE with Crystal Seal. CrystalSeal is a Halliburton product intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is water swellabie dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal can swell to 400 times original size by absorbing water. Due to the swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate taking injection. Procedure: Coil Tubing 1) Pull Isolation Sleeve from the B LEM at 7784' MD. '/ 2) Set a Diverter in the B LEM at 7784' MD to enable access to 1 E -114L1 lateral. 3) Set a 2.75" min ID Isolation Sleeve in the D LEM at 7465' MD to isolate the 1 E -114L2 lateral. 4) RIH with BHA on 2 "coil tubing consisting from bottom to top of 5' OAL x 2" OD TCP Perf Gun, a 2 -1/8" OD closed Circ -Sub, and hydraulic disconnect. Park perf gun to fire 6 spf large hole charges at 8188 - 8193' RKB in a 4.5" slotted liner above a stuck IBP located at 8261' MD. ✓ Drop ball to fire the gun, then RIH 5' with coil to spot the Circ -Sub over the perf interval. Drop ball #2 to shift Circ -Sub open, then proceed to pump Crystal Seal treatment through Circ -Sub and perfs to seal the MBE. Pump: a) Seawater Pad down coil. Maintain 2.0 bpm rate during treatment through Flush (step g) to monitor treating pressures at constant rate. Swap from Seawater to 2% KCI and pump, b) 2% KCI Water with 0.05 ppg CrystalSeal (4 mm mesh, all stages) down coil. Each stage volume is TBD during pumping based on treating pressures during the stage. c) 2% KCI Water w /0.10 ppg CrystalSeal down CT, or Flush (step g) should we see screen out. d) 2% KCI Water w /0.15 ppg CrystalSeal down CT, or Flush should we see screen out. e) 2% KCI Water w /0.20 ppg CrystalSeal down CT, or Flush should we see screen out. f) 2% KCI Water w/0.25 ppg CrystalSeal down CT, or Flush should we see screen out. g) If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to well while POOH. If screenout indication has not been seen prior to Flush, leave CT x Tbg annulus shut -in and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to MBE while POOH with CT to D LEM, then swap to 73 bbls of Diesel FP down coil, followed by 1 CT volume (-40 bbls) of Diesel to displace Diesel FP to tubing and FP CT, followed by SD. RD CTU. Wait 6 hrs before returning 1J -136 to PWI for post- treatment injectivity evaluation. Page 1 of 1 • Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, June 10, 2011 2:31 PM To: Gauer, Jenn L; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt Subject: LPP /SSV Returned to Service on 1E-114 - 06 -10 -2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1E -114 (PTD 204-171, 204 -172 L1, and 204 -173 L2) was returned to service on 6/10/2011 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 543 psig; injection rate is 1903 bwpd. This pilot had been defeated on 5/19/2011 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Daniel Bearden /David Lagerief CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 pager 659 -7000 765 ,,, ,. Y } . , ,i ) JG'v : 3 `l From: Gauer, Jenn L Sent: Thursday, May 19, 2011 5:18 PM To: CPF1 Prod Engr; "Maunder, Thomas E'; "Regg, James B' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Gauer, Jenn L; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt Subject: LPP /SSV defeated on 1E -114 - 05 -19 -2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1E -114 (204 -171, 204 -172 L1, and 204 -173 L2) was defeated on 05/19/2011 when the well was returned to injection service after being shut since 10/26/10. Current wellhead pressure (as of 1715 05/19/11) is 21 psi at an injection rate of 1915 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. 7r ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 6/13/2011 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Thursday, May 19, 2011 5:18 PM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Gauer, Jenn L; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt p Subject: LPP /SSV defeated on 1E-114 - 05 -19 -2011 Tom / Jim, The low pressure pilot (LPP) on tri- lateral injector 1E- 1141204 -171, 204 -172 L1, and 204 -173 L2) was defeated on 05/19/2011 when the well was returned to injection service after being shut since 10/26/10. Current wellhead pressure (as of 1715 05/19/11) is 21 psi at an injection rate of 1915 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 MAY 2 3 101 5/23/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS t. operations Performed: Abandon Repair well ]`", Plug Perf orations f Stimulate Other j;�", Matrix Bypass Alter Casing Pull Tubing Perforate New Pool r Waiver F Time Extension Event Change Approved Program Operat. Shutdow n �" Perforate Re -enter Suspended Well ]" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory Is 204 -171 3. Address: 6. API Number: Stratigraphic J" Service r' P. O. Box 100360, Anchorage, Alaska 99510 4 50- 029 - 23223 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651 1 E -114 9. Field /Pool(s): Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 11857 feet Plugs (measured) None true vertical 3788 feet Junk (measured) 8261 Effective Depth measured 11770 feet Packer (measured) 7414, 7732, 8570 true vertical 3780 feet (true vertucal) 3478, 3547, 3697 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108 20 108 108' SURFACE 4197 10.75 4197 2295 INTERMEDIATE 8736 7.625 8736 3725 LINER 3287 4.5 11856 3788 M Perforation depth: Measured depth: slotted liner from 8781'- 11789' True Vertical Depth: 3731' -3782' OCT 2 zQ�Q kJosilm s C ons. c ', on Tubing (size, grade, MD, and TVD) 4.5, L -80, 7446 MD, 3486 TVD Aneh818P Packers & SSSV (type, MD, and TVD) PACKER L2 - D -SAND ZXP LINER TOP PACKER @ 7414 MD and 3478 TVD PACKER - B -SAND ZXP LINER TOP PACKER @ 7732 MD and 3547 TVD PACKER - A -SAND HRD ZXP LINER TOP PACKER @ 8570 MD and 3697 TVD NIPPLE - CAMCO D13-6 NIPPLE @ 522 MD and 521' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: V 4 ANN WNGV 042010 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 435 Subsequent to operation 564 13. Attachments 14. Well Class after work: ` Copies of Logs and Surveys run Exploratory Development Service Stratigraphic II Gas WDSPL rG STOR Well Status after ic�r O � i � Daily Report of Well Operations _XXX WINJ WAG GINJ r SUSP SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -111 Contact John W. Peirce () 265 -6471 Printed Name John W. Peirce Title Wells Engineer Signature Phone: 265 -6471 Date ^ X12 -7/10 MS OCT 49 a . Z �,,, Form 10-4 4 Revised 1 /2010 � l Submit Original Only .'� 11111149 1 E -114 Well Work Summary DATE SUMMARY 9/25/10 SET CATCHER ASSY @ 7370' RKB (TOP @ 7351' SLM). PULL DMY VLV @ 7070' RKB. IN PROGRESS. 9/26/10 PULLED DMY VLV @ 4477' RKB. SET 1" HES -SPG's @ 4477'& 7070' RKB's. PULL CATCHER ASSY @ 7351' SLM. JOB COMPLETE. 9/30/10 PULL TYPE 1 ISO SLEEVE FROM B LEM @ 7784 RKB,SET IBP @ 7905 CTMD, POH, FP WELL,OOH HYD DISCONNECT PARTED OUT,BALL NOT SEATED ON DISCO, BACK TOMORROW,PLUG NOT SET, 10/1/10 PUSH 2" PIG THRU COIL INSEARCH OF 1/2" BALL, FAILED TO FIND BALL,1 1/2" PIECE OF CMT RECOVERED, PERFORM FSHNG RUN FOR IBP @ 7905 CTMD, UNABLE TO ENGAGE FISH @ 7905, PUSHED FISH TO 8261 TO LATCH, 7 UP JAR LICS & SEVERAL 37K OVER PULLS, FAILED TO FREE IBP, PUMPED OFF, LEFT FISH IN HOLE @ 8261 CTMD, FP WELL, BACK TOMORROW TO RUN DIVERTER & ISO 10/2/10 SET A TYPE 1 DIVERTER IN THE B LEM @ 7784 RKB, SET A TYPE 2 ISO SLEEVE IN THE D LEM @ 7465 RKB, FP, WELL SHUT IN. 10/6/10 PUMP 180 DEG SEAWATER DOWN TBG @ 1 BPM TO PRE -WARM WELL FOR MBE WAX JOB PREP. WSR COVERS 10/6/10 THROUGH 10/9/10. * **LOOK IN ATTACHMENTS FOR PUMP REPORT * * ** 10/10/10 ATTEMPT TO PLACE NOZZLE AT KNOWN MBE IN B -LAT @ 8690' RKB BUT TAGGED UP @ 8240' CTMD. PUMP 9 BBLS OF 105 DEG MELT POINT WAX W/ 5% VYBAR 260 HARDNER. WELL TO STAY SHUT IN, WELL F/P W/ DIESEL. JOB COMPLETE. 3 1�' KUP 1 E -1 ConocoPhilljps Well Attributes Max, Angle & MD _ TD Wellbore APUUWI Field Name Well Status Ind ( °) MD (ftKB) Act Bt. (ftKB) 500292322300 WESrSAK �IN 95 - -10 9,632.41 126070 C ent H2S (ppn) Date Annotator End Data KB-Grd (ft) Rig Rebase Date -.- Wxllc n 1 r1g,1 a pio 75710-Ann SSSV: NIPPLE �_ - Last WO 31.52 10!26/2004 :,._91.1.2 - . 9 Snt�- - Aqua! - A tation Last Tag Depth (ftKB) End Date Annotat on Lest Mod By End Data covouc roz, • ' Rev Reason: Diverter B LEM, ISO SN D LE M Imosbor 10/3!2010 NlprL s2z � _ Casing_ Strings r� SURFACE, -- 'Siring OD String ID Set Depth Set Depth (ND) String Yin String 4,197 C asmg De c ription (in) (in) Top (frKB) (ftKB) (ft (WS/ft) Grade St ring ToP Thrd GAS LIFT, - - 4,a77 CONDUCTOR 20 19.124 0.0 108.0 108.0 94.00 K - 55 WELDED GAUGE,,1,417 GAS 'T SURFACE SURFACE 103/4 9.590 0.0 4,197.0 2,296.2 45.50 L BTC 7.070 GAUGE.7,070 `. WINDOW L7 7.65 6.625 7,778.0 7,790.0 3,559.2 29.70 L-80 BTC -M SLEEVE -C, - -- - - - -- 7,370 INTERMEDIATE 7 518 6 625 - 0.0 8,736.0 3,724.6 29.70 L C - M Pad(er L2, l 7,414 p` - _ WINDOW l2 75!8 6.625 7,465.0 7,477.0 3,492.0 - -_ SS .7,4333 LINER 41/2 3.958 8,569.0 11,856.0 3,788.2 12,60 L DWC Hanger Tubing Strings__ WINDOW L2, _ _ String OD I String ID I I Set Depth Set Depth (ND) Str ng Wt Str ng - -- - 7.477 Tubing D caption (In) (in) Top (ftKB) (ftKB) (NK B) Ui'g G de string Top Tl r. P SBR 1- 1 R ,7,732 - - -- SBR , 7,751 - TUBING 4 12 3.958 0 0 7 446 11 3,485.5 12.50 L IBT SBR. 7.751 - .._... _. _._ Hanger L1, Other In Hole All Jewel : Tubin Run & Retrievable, Fish etc. 7.777 Hanger Lt, , -..,. Top Depth 7,780 (TVD) Top Intl SLEEVE, 7,784 L,070.0 (ftKBI C) Descd don Co mment Run Date ID ( in __- DIVER T 520.7 11.91 NIPPLE CAMCO DBS NIPPLE 10262004 3.875 WINDOW Lt, -- 7,790 �' y 2,398A 70.08 GAUGE PIES SPG set in GUM #1 926/2010 0000 FISH, $261 ---- PACKER, 8, 570 _ 2,398.4 70.08 GAS LIFT CAMCO/KBG2/1/DMYlBK-5/!! Comment: STA 1 4/3/2005 3.938 HANGER. - . __. _ a.ss1 3,389 6 71.88 GAS LIFT CAMCO/KBG Commem: STA 2 4/32005 3.938 NTERMEDIATE, 8,736 t ! 3,389.6 71.88 GAUGE HES SPG set in GUM W2 926!2010 0.000 e,7si 7,370.0 3,468.6 76.75 SLEEVE -C BAKE - SLIDING CMU SLEEVE - CLOSED 11 /12004 10/252004 3.810 ,,,, IPE R F , 7,418.0 3,x79.3 77.16 SEAL - • 5.500 s.o29, 7,414.0 3,478.4 7J.13 Packer L2 I' BAKER LOCATOR /SBE SEAL ASSEMBLY 10125/2004 D -SAND ZXP LINER TOP PACKER 10262004 3.875 7,.2- 243 l 7,433.0 3,452.7 77.29 SBR L2 D -SAND 190 -47 CASING SEAL BORE RECEPTACLE 10262004 4.750 IPE 9976 -9,66 0 7,446.0 3,485.5 R. SHOE BAKER MULE SHOE 10252004 3.875 IPERF, ,_ _ -� 990,110,160 7,463.0 3,488.8 77.16 Hanger L2 D - SAND LEM INSIDE HOOK HANGER 10252004 5.500 IPERF, 10,191 - 10.318 �- 7,465.0 3,489.3 77.16 SLEEVE -C TYPE 2 ISO SLEEVE SET IN D -LEM 102/2010 2.590 IPERF, . _ _.. -. 10, 10.524 7,732.0 3,547.4 77.58 PACKER BSAND ZXP LINER TOP PACKER 10/172004 5.500 IPERF, SD,555 10.997 - 7,7510 3,551.5 77.89 SBR BSAND 19047 CASING SEAL BORE RECEPTACLE 10/172004 4.750 IPERF. 10,627- 10.869 �� IPERF 7,751.0 3,551.5 77.89 SBR Lt - B -SAND 19047 CASING SEAL BORE RECEPTACLE 10/172004 4.750 10,700 -10,742 7,777.0 3,556.6 78.32 Harper Ll B -SAND BAKER MODEL Bt FLANGED HOOK HANGER 10/172004 4.500 IPERF, 10,805- 11 7,784.0 3,558.0 78.43 11,321 - 11,65/ Harper Ll B -SAND LEM INSIDE HOOK HANGER 10/172004 4.750 IPERF, '~- - � - IPERF, 7,794.0 3,558.0 78.43 DIVERTER - TYPE DIVERTER SET IN 8 LEM @ 7784' 10212010 3.130 11,716 - 11.788 - - - LINERLI, 6,261.D 3,642.8 80.06 FISH 3" BAKER IBP @ 8261' CTMD IN B- LATERAL 10/12010 0.000 n.a08 8,570.0 3.696.7 79.89 PACKER - ASAND HRD ZXP LINER TOP PACKER 10/8/2004 5.500 NE1, L2, 11,eo9 8,591.0 3,697.0 77.44 1 HANGER I A-SAND FLEXLOCK LINER HANGER 10/8/2004 5.500 Perfora & Slots Shot Top (ND) Stm (TVD) Dens Top flK6 Btrn (ftKB (ftKB) I (ftKB) Zone Date (sh.. T Commend 8,781.0 8,903.0 3,731.4 3,742.4 WS A2, 1E -114 10/812004 40.0 IPERF Slotted liner, 2.5" x .125" slots 9,027.0 9,089.0 3,752.0 3,758.5 wS A2, 1E -114 1018!2004 40.0 IPERF Slotted liner, 2.5" x.125" slots •- -- - - -. 9,120.0 9,450.0 3,757.8 3,751.0 WS A2, 1E -114 10/82004 40.0 IPERF Slotted liner, slots every other joint 9,576.0 2660.0 3,741.3 3,736.2 WS A2, 1E-114 101&2004 40.0 WERE Slotted liner, 2.5" x.125" slots 9,909.0 10,160.0 3,735.8 3,751.9 WS A2, 1 E -114 10/8/2004 40.0 IPERF Slotted liner, 2.5" x .125" slots --_.- - _. -- -._ _� 10,191.0 10,355.0 3 .0 3,762.8 WS A2, 1 E -114 10/8/2004 40.0 WERE Slotted liner, 2.5" x .125" slots 10,482.0 12524.0 3,768.3 3,768.9 WS A2, 1 E -114 1002004 40.0 IPERF Slotted liner, 2.5" x.125" slots 10,555.0 10,597.0 3,7695 3,768.4 WSA2, 1E -114 10/8/2004 40.0 IPERF Slotted liner, 2.5 "x ... 125 "slots 12627.0 10,669.0 3,768.8 - - 3,768.5 WS A2, 1 E -114 101 8/2004 40.0 IPERF Slotted liner, 2.5" x .125" slots -- 10,700.0 10,742.0 3,767.7 3,766.7 WS A2, 1 E -114 10/8/2004 40.0 IPERF Slotted liner, 2.6"x.125" slots 10,805.0 11,095.0 3,764.1 3,746.7 WS A2, 1 E -114 10/82004 40.0 IPERF Slotted liner, 2.5"x.125" slots 11,321.0 11,654.0 3,750.7 3,769.7 WS A2, 1E -114 10/8/2004 40.0 IPERF Slotted liner, slots every other joint 11,716.0 11,789.0 3,7743 3,781.5 WS A2, 1 E -114 10/8/2004 40.0 WERE ,Slotted liner, 2 5" x .125" slots Notes: General & Safet End Date Annotati on 1012612004 iNOTE: TRI- LATERAL WELL 1E -114 (A- SAND) 1E -114L1 (B -SAND) 1E -114L2 (D -SAND) i LINER, TD (t E - - J 114), � -- 12,607 MEMORANDUM To: Jim Regg '~~~ -7f Z,G ~ i~ P.I. Supervisor L FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-114 KUPARUK RIV U WSAK 1E-114 Src: Inspector NfIN_C'(1NFi11F.NTiAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV U WSAK 1E-114 API Well Number: 50-029-23223-00-00 Inspector Name: Bob Noble mitRCN100628073514 Insp Num: Permit Number: 204-171-0 Inspection Date: 6/24/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E-114 Type Inj. ~ TVD 3478 .. IA 926 T 2460 ~ 2435 2435 P.T.D 041710 TypeTCSt SPT Test psi QA ~ 30 2460 65 66 66 Interval 4YRTST p~F P ~ T ub ~ 730 735 735 ~ 735 Notes: , , °~ .411?-.$(P^. !1111 r~~J ~~„~ Wednesday, June 30, 2010 Page 1 of 1 John Peirce ~J Wells Engineer L ,;~,~~ App ;- '~ ~~ ~~~ ~~ ~ ~ ~ / ConocoPhilhps Alaska,:.l~x~,. ~- P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1 E-114 Sundry Number: 310-111 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of April, 2010. Encl. STATE OF ALASItA 41 ~' ~" ~ °~'~"" IL AND GAS CONSERVATION COMMISSI TION FOR SUNDRY APPROVALP~~ 0 ~~ 2010 20 AAC 25.280 1. Type of Request: Abandon ~ Rug for Redrill ~ Perforate New Pool ~""` Re ogram r Suspend ~ Rug F2rforations Ft?rforate ~ Pull Tubing ~° Af11 Time Extension A X T~Ei4T A'IEN~ Operational Shutdow n ~ Re-enter Susp. Well Stimulate Atter casin g ~ Other: atrix Bypass Event r` 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Devebpment ~"' Exploratory 204-171 ' 3. Address: Stratgraphic ~`"' Service Jy 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23223-00 • 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 ', 1E-114 9. Property Designation: 10. Field/Pool(s): ADL 25651 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11857 3788 11770' 3780' Casing Length Size MD ND Burst Collapse CONDUCTOR 108 20 108' 108' SURFACE 4197 10.75 4197' 2295' INTERMEDIATE 8736 7.625 8736' 3725' LINER 3287 4.5 11856' 3788' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted liner from 8781'-11789' 3731'-3782' 4.5 L-80 7446 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NIPPLE - CAMCO DB-6 NIPPLE MD= 522 ND= 521 PACKER L2 - D-SAND ZXP LINER TOP PACKER MD= 7414 ND= 3478 PACKER - B-SAND ZXP LINER TOP PACKER MD= 7732 ND= 3547 PACKER - A-SAND HRD ZXP LINER TOP PACKER MD= 8570 ND= 3697 12. Attachments: L~scription Summary of Proposal ; 13. Well Class after proposed work: • Detailed Operations Program ~" BOP Sketch ~ E~loratory ' Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/10/2010 Oil ~"`` Gas r WDSPL Suspended 16. Verbal Approval: Date: WINJ ~ GINJ WAG ~` Abandoned Commission Representative: GSTOR ~ SPLUG ~"`` 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Engineer D ~ r J~ - ate O Phone: 265-6471 Signature it.. ' Commission Use Onl Sundry Number~~ /1, I I Conditions of approval: Notify Commission so that a representative may witness V Plug Integrity "` BOP Test "` Mechanical Integrity Test ~ Location Clearance )°" Other: Subsequent Form Required: ~ Q ' ~ ~ 7 APPROVED BY ~~~ ~ I Approved by: COMMISSIONER THE COMMISSION Date: ` C~~.~~ ro ALA APPLI A Form 10-4a9~It~V1t~ 1~P0100 ~ ~ ~ ~ ~ ~ ~ A L rbmit in Duplicate . L~ 1 E-114L1 Proposal to Wax Fill the B Sand MBE Proposal Bi Objective: 1 E-114L1 is a B sand lateral with 4.5" slotted liner. A matrix bypass event (MBE) occurred in - 114L1 on 3/20/06 to 1 E-168L1 producer. A 3/23/06 (PROF in 114 shows 100% PWI entering the B sand. A 4/12/06 IPROF in 114L1 saw a robust MBE at 8690' MD at the heel of 114L1. On 6/30/06 an Iso-sleeve was set in the B LEM, and 1 E-114 has since been on D & A only PWI. The Iso-Slv will be pulled from the 114 B LEM and a Plug will be set to isolate the A lateral. Next, a diverter will be set in the B LEM, and an Iso-Slv will be set in the D LEM to halt cross flow. In 1 E-168, the B lso-Slv will be pulled to allow inflow from the MBE, and an Iso-Slv will be set in the D LEM to halt cross flow. To reduce plant upset potential, pumping a 1 E-114L1 Step Rate Injection Test (BRIT) will be contingent upon the quality of 1 E-105L1 BRIT data. We would prefer to use 1 E-105 BRIT analog data (1 E-105 will be our first ever wax job) to determine fluid temperature pumped through an Active-Coil (I-Coil) nozzle at MBE depth vs. various pump rates to determine the pump rates needed for placing liquid wax into the MBE. An Active-Coil job will be performed to seal the 114L1 MBE using 125 F melting point wax heated to 180°F at surface. The hot wax will be pumped down coil to the MBE at 8690' MD as liquid and will be displaced by 130 - 160 F diesel to the MBE, followed by shutdown to let the wax solidify in the MBE to West Sak reservoir temperature of ~72 F. Work Sequence: 1 E-114 Injector Work 1 E-168 Producer Work CT Pull 'B' Iso-Sleeve CT Set `A' Lateral Plu halt otential crossflow CT Set'B' Diverter CT Set 'D' Iso-Sleeve halt otential crossflow Pull 'B' Iso-Sleeve o en access to MBE Set'D' Iso-Sleeve .halt otential crossflow Contingent SR/T: Use Active-Coil with Distributed Temperature Survey (DTS), with 180°F Seawater pumped in 1 coil volume stages at various rates ranging from 1.5 bpm to 0.5 bpm. Verify an open MBE with DTS across trunk of MBE, and by WHIP vs. In' Rate indicators. Pump Wax Job: Use Active-Coil with Distributed Temperature Survey (DTS). Pump 100 bbls 180°F Seawater at 1.5 bpm to ensure open ~ preheated MBE, followed by 10 bbls 180°F Wax at 1.5 bpm, followed by 1 Coil volume of warm Diesel displacement at 1.5 bpm gradually slowed to decreasing rates to put the tail of the wax slug into the MBE just a few degrees above cloud point, followed by shutdown to let wax solidify in MBE. Wait on Wax 4 da s to `cure'. Return to `B' sand onl PWI Flow as `B' sand onl ;evaluate Wax 'ob Pull'D' Iso-Sleeve Pull `B' Diverter Pull `A' Plu Pul! `D' Iso-Sleeve Restore PWI to A, B, and D laterals Restore roduction from A, B, and D laterals Cc7r ~c~tiPhiilips r ~~..zi lr)q, __ __WemC fiy, i-1116177!2 ___.. Stll~naf _. AC6 CONDUCTOR,_ SURFACE. \_ J 4,197 GAS LIFT,1 4 477 \ 1 GAS LIFT, 1 ] 070 SLEEVE-c, ],3]0 Packer L2. 7,414 SEAL. 7.418- _ SBR L2. 7,433 SHOE. 7.x46 Hanger L2, ] 463 WINDOW L2. 7.477 PACKER. 7.732 SBR ] ]51 SBRL1 7751 Han97r777 Hanger L1, 7.784 SLEEVE,7784 wwoowu, r___ 9, 7.8 s, s,s to.t 11,321-11 654 IPERF. 11,7tfi-11.789 LINER Li, 1 soa LINFR L2, 11.809 KUP W II Attr-butes Annotation Depth (ftK61 ~i ~Entl Da Last Tag I CasingStrin~s string oo so- Casing Description (inl I I CONDUCTOR 20 SURFACE 10 3/4 WINDOW L7 7.65 _ INTERMEDIATE 7 5/8 WINDOW L2 7 5/8 e e Welltwre APVUWI Fieltl Name 500292322300 (WEST SAK commem iN2s (p SSSV_NIPPLE ' 1E-114 Max Angle 8 MD _ f TD Status Inc! (°) MD (ftK6) ~. Act Btm (ft KB) I 95.10 9,632 41 12 607 0 i End Date KB-Grtl (ftj Rig Release Date I ~ ~ 31-52 ~ 10/26/2004. . Last Motl By Entl Date Reason: 29.70 17.856.0 String ID Set Depth Set Depth (TVD) I Str ng wt Jtrmg (in) Top (ftK8) (NKB) (tiKBl (lbslft) Grade Stnng Top Thrd 3 958 QO 7 446.0 3 485.5 12 50 L 80 IBT ': Tubin Run & Retrievable, Fish etc. Top Deptn (TVD) Top Intl To_p (ftK6) (NKB) (°) Description Comment Run Date ID (ini 522 520.7 11.97 NIPPLE CAMCO DBb NIPPLE 70126/2004 3.875 4,477 2,398.4 70.08 GAS LIFT CAMCOlKBG-2/11DMY/BK-5/// Comment: STA 1 4/3/2005 3.938 7,070 3,389.61 71.88 GAS LIFT ~ CAMCO/KBG-2/1/DMY/BK-5/// Comment STA 2 4/3/2005 3.938 7,370 3,468.61 76.75 SLEEVE-C i BAKER SLIDING CMU SLEEVE -CLOSED 71/1/2004 10/25/2004 3.810 7,474 3,478.4 77.13 Packer L2 D-SAND ZXP LINER TOP PACKER 10/26/2004 ~ 5.500 7,418 3,479.3 77.16 SEAL BAKER LOCATOR/SBE SEAL ASSEMBLY 70/25/2004 ~ I 3.875 7,433 3,482.7 77.29 SBR L2 D-SAND 190-47 CASING SEAL BORE RECEPTACLE 10!26/2004 4.750 7,446 3 485.5 77.40 SHOE BAKER MULE SHOE 10/25!2004 3.875 7,463 3 488.8 77.16', Hanger L2 D-SAND LEM INSIDE HOOK HANGER 10/25/2004 5.500 7,732 3,547.4 77.581 PACKER B-SAND ZXP LINER TOP PACKER 10/17/2004 SS00 7,751 3,557.5 77.89 SBR 6-SAND 790-47 CASING SEAL BORE RECEPTACLE 10/17/2004 4.750 7,751 3,551.5' 77.89 SBR Ll B-SAND 19047 CASING SEAL BORE RECEPTACLE 10/17/2004 4.750 7,777 3,556.61 78.32 Hanger L7 ' B-SAND BAKER MODEL B7 FLANGED HOOK HANGER 10/17/2004 i 4.500 7,784 3,558.0 78.43 Hanger L1 B-SAND LEM INSIDE HOOK HANGER 10/17/2004 ~ 4.750 8,570 3,696.7 79.89 PACKER A-SAND HRD ZXP LINER TOP PACKER 1G/SI2004 5.500 8,591 3,697.0 77.44 HANGER A-SAND FLEXLOCK LINER HANGER 10/8/2004 5.500 :rfora tions 8 - Slots - - - _ ___ _ - _ _ _ ~ snot Top (TVD) Btm (TVD)( Dens t (ftK8( ~ Btrn (ftK8) (ftK6) (ftK8( Zone Date ish-. Type _ Comment 8,781 i 8,903 3,731.4 3,742 4 WS A2, 1 E-114 10/8/2004 40.0 IPERF i Sootted liner, 2.5" x .125" slots 9,027 9,089 3,752 0 3,758.5 WS A2, 1 E-114 1018/2004 40.0 IPERF Slotted liner, 25" z .125" slots 9,120 9450 3,757.8 3,751.0 WS A2, tE-114 10/8/2004 40.0 1PERF Slotted liner, slots every otherjoint 9,576 9,660 3,741.3 3,736.2 WS A2, tE-714 10/8/2004 40.0 IPERF Slotted liner, 2.5" z .125" slots 9,909 10,160 3,735.8 3,757.9 WS A2, tE-174 10/8/2004 i 40.Oi IPERF Slotted liner, 25" z _125" slots 10,191 10,358 3,754.0 3,762.8 WS A2, tE-114 10/8/2004 40 O~ IPERF Slotted liner, 2.5"x.125"slots 10,482 10,524 3,768.3 3,7689' WS A2, 1E-114 1 10/8/2004 40.0 IPERF Slottetl liner, 25"x.125"slots 10,555 10,597 3,769.5 3,768.4 WSA2, 1E-174 ; 10/8/2004 40.0 IPERF Slotted liner, 25"x.125" slots 10,627] 10,669 3,768.8 3,768.5 WS A2, 1 E-114 ~ 10/8/2004 40.0 IPERF Slotted liner, 2.5" x .125" slots 70,700 10,742 3,767.7 3,766.7 WS A2, 1 E-114 70/8/2004 40.0 IPERF ' Siottetl liner, 25" x .125" slots 10,805 17 095 3,764.1 3,746.7 WS A2, tE-114 10/8/2004 40.0 IPERF l Slotted liner, 25" x .125" slots 11.321 1 11.654 -..-1.750.7 3.769./ WS A2, tE-714 10/8/2004 40.O ~IPERF (Slotted liner, slots every other joint 11,716 11, 789 3,774 3 3 78 t_5 WS A2, 1E-114 10/8/2004 40.O ,IPERF ~ Slotted Inver, 25" x .125" slots >tes: General & Safet y End D ate Annota tion - 26/2004 (NOTE: TRI-LATERAL WELL 1E-114 (A-SAND) 1E-114L1 (B-SAND) 1E-114L2 (D-SAND) LINER. 11,656 TD (1 E-1 t4), 12,607 ,,r ~~~~~ l) ~ 100fJ ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~N~~ s~~ ~ ~~~~ Well Job # Log Description ^; ~.~c ~ A ~ ~~~ -N N0.4852 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 08/28/08 2W-11 12100437 PROD PROFILE ~~, - 08/06/08 1 1 1 F-14 12096521 PROD PROFILE - ~ 08/08/08 1 1 1 Y-05 12096520 LDL J (p ~ 08/07/08 1 1 30-02A 12097415 SBHP SURVEY ~- a 08/10/08 1 1 1 E-114 12096524 INJ PROFILE - 08/10/08 1 1 2A-24 12097417 PROD PROFILE - ~ ~ 08/11/08 1 1 1 G-10A 12097418 PROD PROFILE 9 08/12/08 1 1 1 L-14 10228963 INJ PROFILE 1- 1(~ 08/12/08 1 1 30-17 11966273 SBHP SURVEY i - 08/15/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. / ~; -- ~' ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA_ 99510-0360 April 16, 2008, . Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~ APR ~ ~ 2008 Dear Mr. Maunder:. • RECEIVED ... APR 2 2 2008 ~a ai ~ c~ cons, commi~ior, an~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 entexing 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 corrosion inhibitor/sealant was pumped on 3/29/2008. 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. Sind :'~~ Perr ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface' Casing'by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field fl~4n '- 3/2 9/2008 Well Name PTD # Initial top of cement ft Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date 1 E-34 197-166 9" bbls ft al 1 E-102 204231 14" NA 9" NA 7 3/29/2008 1 E-114 204171 24" NA 14" NA 8 3/29/2008 1 E-126 204122 25" NA 24" NA 16 3/29/2008 1 E-166 204-153 20" NA 25" NA 14 3/29/2008 NA 20" NA 12 3/29/2008 ConocoPhillips April 14, 2007 N APR ~ 2008 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage AK 99501 Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 RECEIVED aPR 1 s Zoos Alaska 0~ & Gas Cons. Commission Anchorage ~~ ~ _ X71 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set blanking sleeves in the Lateral Entry Modules (LEM) of two West Sak multilateral injection wells. Enclosed you will find 10-404 Reports of Sundry Well Operation for ConocoPhillips Alaska, Inc. for - - E-I14, and 1E-114L1. These reports record the setting of an LEM isolation sleeve in the L1 lateral for each of these two water injection wells. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Sincerely, //p G~ ~~ Robert W. Buchholz Attachments ECEIVE® STATE OF ALASKA APR 1 6 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~p~~1 & Gas Cons. Commission _L.-~ 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ et L1-LEM Isolation Sleeve 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: ConOCOPhilllps Alaska, InC. Development ^ Exploratory ^ 204-171 3. Address: Strati ra hic g p ^ Service ~ ' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23223-00 -. 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-114 ' 8. Property Designation: 10. Field/Pool(s): ALK 25651, ADL 469 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11857' • feet true vertical 3788' • feet Plugs (measured) Effective Depth measured 11770' feet Junk (measured) true vertical 3780' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE (45.5 ~ 4102' 10-3/4" 4197' 2296' INTERMEDIATE 8641' 7-5/8" 8736' 3725' D-SAND WIND01 1' 7-5/8" 7466' 3490' B-SAND WINDOW 1' 7-5/8" 7779' 3557' LINER-ASAND 3287' 4-1/2" 11856' 3788' Perforation depth: Measured depth: Slotted Liner 8781'-11 789' true vertical depth: 3731'-3781 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7446' MD. Packers &SSSV (type & measured depth) PKR= HRD ZXP Liner Top Packer PKR= 8570' SSSV= NIPPLE SSSV= 522' 12. Stimulation or cement squeeze summary: Intervals treated (measured) . _ ~~:. ~ ~~ ~~~ ~ ;~ ZQ~Q ,APR 2 5 20 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 2452 1039 60 Subsequent to operation 2215 1511 519 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 ' Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buch of Title Production Engineering Technician Signature Phone 659-7535 Date ~ - - ~ Form 10-404 Revised 04/2004 ~~~ t.,,/ ~ C t i i ~ ~ ~ ~y Submit Origi nl~~j } `~ tt t ~ (l G~ 1 E-114 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/30/06 04/13/06 Pushed B" lateral ISO sleeve an additional 2' into profile with Baker Hipp tripper to 7784' RKB, ran PDS temp & spinner with well on injection @ 2000 BPD. Verified that ISO sleeve is finally set with no injection going to "B" lateral." ~-- PULL DIVERTER FROM B" LEM AND SET ISOLATION SLEEVE ACROSS "B" LEM AT 7784' RKB." /~ KRU 1 E-114 I LL~ ConocoPhillips Alaska, Inc. • • __ fT ~' J tircu...+'~ . ,y. - ~.~.- ~, ,_ - 4 F~ +,-y,yg~,rDt '' MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFicl~\CvrPgs_Inserts\Microfilm_Marker.doc LPP Defeated On West Sak Injectors at DSlE e e Tom / Jim, The Low Pressure Pilots for 1 E-1 02, 1 E-1 05, 1 E-112, and 1 E-114 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: 1E-102 822 BWPD, 541 PSI 1E-105 1006 BWPD, 660 PSI 1E-1121937 BWPD, 597 PSI ---... 1E-114 945 BWPD, 562 PSI 'da4 - \ '" \ This email is in accordance with Administrative Approval No, CO 406B.001. Regards, Hai .............. 4Ø- Hai Hunt / Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com SCANNED JAN 1 6 2007 ":; ~ "''';.!':',.,:..~1 1 of 1 1/16/2007 11:07 AM ~ b M,,, '2 ~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041710 Well Name/No. KUPARUK RIV U WSAK 1E-114 Operator CONOCOPHILLlPS ALASKA INC S,tJ.á 2¡- hi ~~ API No. 50-029-23223-00-00 MD 11857' TVD 3788 /' Completion Date 10/26/2004 /' Completion Status 1-01L Current Status 1WINJ UIC Y .-- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes --- DATA INFORMATION Types Electric or Other Logs Run: GrlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data TYR pt L.e~ ~. Electr Digital Dataset Med/Frmt Number . £ð"ie "'..~ w...Ll Log Log Run Interval OH/ Scale Media No Start Stop CH 0 11857 Open 5- CQI aeee 8ê2Q O¡:'ðlr 2,';- Blu 108 11857 Open Name Directional Survey Log ~ Induction/Resistivity 2, >- Blu 108 Received Comments 11/15/2004 =1 11/£8/2Ð84 "iIP^'Iiib.b."T5C TRf.CroR 5/18/2005 MULTIPLE PROPAGATION RESISTIVITY-GAMMA RAY -RWD 11857 Open 5/18/2005 MULTIPLE PROPAGATION RESISTIVITY-GAMMA RAY-RWD 1~lnduction/Resistivity I~~ c:rc09 ~ 13120 LIS Verification Injection Profile 5 Blu 108 7190 11857 Open 5/18/2005 7834 Case 3/24/2006 With WellTec Tractor 23- Mar-2006 I ¡ I I ~ --- --~---- Name Interval Start Stop Sent Received Sample Set Number Comments . Well Cores/Samples Information: ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? §: Chips Received? Y I N - Formation Tops Analysis Received? ~. Comments: Permit to Drill 2041710 MD 11857 -- DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Well Name/No. KUPARUK RIV U WSAK 1E-114 TVD 3788 Compliance Reviewed By: Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23223-00-00 Completion Date 10/26/2004 Completion Status 1-01L Current Status 1WINJ UIC Y ~ ~~-~- ~ ~~\J~ 5- Date: . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Keótí 6rt (DC:., P.I. Supervisor 7. ( DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-114 KUPARUK RIV U WSAK IE-I 14 ,\.-\1\ ~()'"\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv---r-.¡;::;ß'~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK. IE-114 API Well Number 50-029-23223 -00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060605135254 Permit Number: 204-171-0 Inspection Date: 6/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! IE-I 14 ¡Type Inj. I W I TVD 3478 I IA I 1670 I 2460 I 2450 2450 ! P.T. I 2041710 TypeTest i SPT , Test psi 1500 lOA ¡ 60 i 70 I 70 70 Interval 4YRTST PIF P Tubing i 300 , 300 i 300 300 , Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integriy Wednesday, June 07, 2006 Page 1 of 1 UPDATE: LPP Variance for West Sak injection welllE-114 (PTD ... . . Subject: UPDATE: LPP Variance for West Sak injection well 1E-l 14 (Pm 2041710) From: NSK Problem Well Supv <n1617@conocophillips.com> '----t ';).04 -t"L j. Date: Mon, 27 Jun 2005 06:46:56 -0800 .;lú 4 - \ "\. ~ To: Thomas Maunder <tom_maunder@admin.state.akus>, James Regg <jimJegg@admin.state.akus> CC: AOGCC North Slope Office <aogcc-prudhoe_bay@admin.state.akus> Tom & Jim, 1E-114 West Sak injector has built sufficient wellhead pressure to set a LPP. The LPP was place back in service last week. Please let me know if you have any questions. Marie McConnell ConocoPhi 11 ips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, May 18, 2005 5:30 AM To: 'Thomas Maunder'; Dethlefs, Jerry C; 'James Regg' Cc: AOGCC North Slope Office; NSK Problem Well Supv Subject: RE: FW: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Tom, 1E-114 (PTD 2041710) was brought on line May 7th and passed the initial MITIA yesterday, witnessed by State Inspector, Jeff Jones. The well is still in the process of "fillup" and tubing continues to operate on a vacuum. The variance to gag the LPP expires on 5-20-05. ConocoPhillips requests approval to extend the gagged pilot approval for an additional 30 days to expire on 6/20/05 or when the surface pressure increase to a level that a LPP can be put in service. Please let us know if this is acceptable. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, April··m·;i""(j'~·-·--2··à"õ·5-··î"Q: 43 "'-AM"" ........__.____.._....m..·..·_· To: Dethlefs, Jerry C Cc: AOGCC North Slope Office Subject: Re: FW: LPP Variance for West Sak injection well 1E-114 (PTD 2041710) Jerry, Given the low surface injection pressure, it is acceptable to "gag" the LPP on lE-114. Please make sure your operators have a copy of this message. Tom Maunder, PE AOGCC Dethlefs, Jerry C wrote: Tom: West Sak injector 1E-114 will be ready for injection later today--can I assume you approve the variance for having the LPP gagged for up to 30 days? The other issues we discussed can wait, but the 10f5 6/27/20058:37 AM UPDATE: LPP Variance for West Sak injection welllE-114 (PTD... . 20f5 . well is almost ready to put on line. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent:* Wednesday, April 20, 2005 7:27 AM *To:* Dethlefs, Jerry C *Cc:* Jim regg@admin.state.ak.us; NSK Problem Well Supv *Subject;*-R-e-:---FW-~--LPP-vãr:Cance-for West Sak injection well lE-114 (PTD 2041710) Good reasoning as to needing something "on paper". Lets talk later today. Tom Dethlefs, Jerry C wrote: Tom: Yes, the subject wells at West Sak are all water injectors--and you are right, we do not perform a State SVS test on these wells. However, we have found it prudent to strive to meet all the regulatory requirements that apply to our areas of operations, especially these days when we are under sufficient scrutiny that we could be found doing something wrong somewhere at anyone particular point in time. The issue here is that the pool rules (Conservation Order #406B, Rule 6, section b) state we either need dual check valves or a single check and fail safe SSV. We do not have dual checks, but do have a single check and fail safe SSV. If the LPP is gagged we have defeated the SSV and so will be out of compliance. We are not going to risk an NOV for lack of approval to gag the LPP. The requests we have been making are for an exemption from the Pool Rules I mentioned above. This is why I suggested we could specify some conditions for a mutually agreeable plan so we can just manage these situations as they come up rather than having to bother you each time on a well by well basis. We need to have something documented in our hand that shows we can deviate (with approval) from the Pool Rules should certain conditions exist (like insufficient wellhead pressure). Let me know your thoughts on this. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- *From:* Thomas Maunder [mailto:tom maunder@admin.state.ak.us] *Sent: * Tuesday, April 19~Ö-õ54~õá-·-PM·_··--.._-_·.....·__·_··_·m_. .-.--------- *To:* NSK Problem Well Supv *Subject:* Re: LPP Variance for West Sak injection well lE-114 (PTD 2041710) Jerry, I thought I sent a response back regarding the settings at Alpine. These WS wells are water injectors aren't they?? I am not sure how all of this works, but to my memory we don't test SSVs on water injectors do we?? MI for sure, but not water and in WS there are only a few wells approved for MI and they are on lC and ID. Let me know your thoughts on this and I will talk to Jim as well, but this may be something we don't need to be looking at. Just my thought for now, subject to change after discussion. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: 6/27/2005 8:37 AM UPDATE: LPP Variance for West Sak injection welllE-114 (PTD... . service. 30f5 . Tom: The following is a request from Operations to operate West Sak injection well 1E-114 with a gagged low pressure pilot. The request is for a period not to exceed 30 days. This is similar to the previous approvals we have requested for the startup of West Sak injectors recently. The Production Engineers believe the reservoir will charge up over time and that these wells will eventually behave with sufficiently high tubing pressure to return to normal LPP protected service. Please let me know if you concur with our plan. Secondly, the previous email is from a discussion we started last week. Rather than ask for approval for these various situations each time they occur, is it feasible to agree on a set of rules so that the concerns of your agency and our company are met without approval on a well by well basis? CPAI could submit a written document with a proposal on how to manage these issues, and if the AOGCC concurs we could be in business. Let me know your thoughts on this approach as well. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 We are requesting a temporary variance for 1E-114 (PTD 2041710) from Conservation Order #406B, Rule 6, section b which requires a SSVs for water injection well to operate. A temporary variance to operate 1E-114 water injection wells with a defeated SSV pilot and without a 24 hr man watch for a maximum of 30 days is requested. Based on previously pre-produced West Sak injectors, this well will be injecting on a vacuum and the SSV low pressure pilot will not be placed in service at this time. This will be the initial injection for 1E-114 and once an established tubing pressure of 300 psi has been reached the SSV pilot will be placed back in working Thanks, *Peter Nezaticky* / Marie McConnell ConocoPhillips Alaska Inc. West Sak Production Engineer ph: (907) 659-7061 Fax: (907) 659-7314 -----Original Message----- *From:* NSK Problem Well Supv *Sent:* Wednesday, April 13, 2005 4:32 PM *To:* 'Thomas Maunder' *Cc:* NSK Problem Well Supv; jim regg@admi.n.sta.te.ak.us *Subject:* RE: LPP Settings for Alpine and West Sak Tom: It would be nice to have a "general rule" or exemption that would apply to all of Alpine when we have this problem. For that matter, it would be nice for West Sak too, for these new injectors with low reservoir pressure. The problem is that not long ago we received approval from your agency to establish 1800 psi as the benchmark LPP setting for gas injectors at Alpine. This has worked out OK until the situation with CD1-06 and 14 (see injection pressure below). These wells are expected to eventually pressure up until they are similar to the others on the pad, however they are not high enough now to use 1800 psi or they will shut-in. Rather than risk another NOV for gagging the LPP we have instead asked for approval to set lower than the 1800 psi guideline. We could make it easier on us both if we agreed on a process to adjust these as needed until they have reached full injection pressure. I don't have a good feeling how 6/27/20058:37 AM UPDATE: LPP Variance for West Sak injection welllE-114 (PTD... . . long that may be--it could be weeks or months. These pilots are easy to change and set since it is largely a software issue, so they can be changed up as needed. If you are willing, I could propose that we just manage this internally until a well reaches it's maximum pressure at which time the standard 1800 psi would apply. For instance, we could say that the LPP must not be set lower than 200 psi below the average daily injection pressure until the injection pressure has reached the mature state. Of course we could document each well that has this problem so that the records could be provided to the Inspector when needed. That would allow us to keep these wells in service without nuisance trips and still provide protection in the case of a release. Should you agree to this type of approval we can formalize it in a letter to your agency. I mentioned earlier the problem with West Sak injectors--our new wells have very low injection pressure and cannot operate with our standard LPP in place of about 700 psi. The injection pressure can be as low as 100 psi on injection and will be vacuum if shut-in. That is the reason for the couple requests recently for a variance to run gagged. We have another (lE-114) that will be on soon that is expected to be near vacuum. I remember years ago when I was at Prudhoe EOA that the water injectors would go on vacuum when shut-in so they were always operated with the LPP gagged. How is that handled with your agency? Is it possible we can do what I proposed above for these cases too? The expectation is with time the injection pressure will increase and a LPP can be used, but initially it is not possible. I am very interested on your opinion on this and if my proposal is something you will consider. As long as we have an agreement in place on how to handle these situations, we can manage it without asking for your approval on a well by well basis. Drop me a line when you have time to review this. I go out tomorrow and MJ will be here, but she can carryon with the issue. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- *From: * Thomas 40f5 13, 2005 3 :40 PM *To:* NSK Problem Well Supv *Cc:* jim reaq@admin.state.ak..us *Subject:* R~~ LPP Setting for Alpine CD1-06 Jerry, Jim and I have discussed this matter. Does it make more sense have you all request a low pressure trip pressure for each pad rather than addressing it on a well by well basis? We are in agreement to have a setting to avoid the nuisance trips. Is this only something encountered when a pattern has low pressure?? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: Alpine Operations has asked me to seek approval to temporarily reduce the LPP set point from 1800 psi to 1600 psi on MI injection well CD1-06. The injection pressure has been averaging just barely over 1800 psi, so any bobbles may shut-in the well. The following note is from the Alpine Lead Operator with more explanation: Now that we have put all the gas down CD1-06 instead of splitting it with CDl-14, the tubing pressure of 6/27/20058:37 AM UPDATE: LPP Variance for West Sak injection welllE-114 (PTD... . . CD1-06 is coming back up slowly. We would like to lower this trip point to 1600 # until we get some room. Do you think we can do this and then we can raise it in 6 months if the formation pressures back up. This well is also our black start Fuel Gas supply well. If we need to operate off this well for very long we would have the Low pressure trip by-passed with a setting of 1800 # that it has now. At 1600 # setting the by-pass would not be used. Rick Alexander 4220 With your approval we will reduce the LPP set point until such time that the tubing pressure increases to a point it can be reset at 1800 psi without nuisance trips. Thanks for your attention on this. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 50f5 6/27/20058:37 AM 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 . 7. KB Elevation (ft): RKB 95' 8. Property Designation: Kuparuk Rver Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE (45.5 ¡ INTERMEDIATE LINER - A SAND Perforation depth: . R.E.· r:Ewr'¡··E- ... ",. \ w". . JUN 0 '1 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS\¡ask~ Oi! (Ii.. 5. Permit to Drill Number: 204-171 6. API Number: 50-029-23223-00 9. Well Name and Number: 1 E-114 10. Fìeld/Pool(s): Kuparuk River Reid I West Sak Oil Pool measured 11857' feet true vertical 3788' feet measured 11770 feet true vertical 6276' feet Length Size MD 108' 20" 108' 4102' 10-3/4" 4197' 8641' 7-518" 8736' 3287' 4-1/2" 11856' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2295' 3725' 3788' Measured depth: 8781-11789 true vertical depth: 3731-3781 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7446' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIPPLE SSSV= 522' Form 10-404 Revised 04/2004 Submit Original Only . 1E-114 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 4/20/200S Commenced Water Injection . I · . . ConocoPhillips Alaska, Inc. API: 500292322300 SSSV Type: NIPPLE Annular Fluid: Reference Loo: 28' RKB Last Tao: Last Tao Date: TUBING (D-7446, OD:4.5DD, ID:3.958) I I - 11716 - 11789 3775 - 3781 Gás...lDift.Mál'iârelsWál.ves St MD TVD Man Mfr I Man Type i 4477 2399 CAMCO, KBG-2 7070 3389 CAMCO KBG·2 .V DescriDtion CONDUCTOR SURFACE (45,5 & 40.5) DescriDtion .ER-ASAND Size I TOD 4.500 I 0 E?eiifQrâ~iönšSUmm'áì'Y' Interval TVD 8781 - 8903 3731 - 3744 9027 - 9089 3753 - 3756 9120 - 9450 3756 - 3751 9576 - 9660 9909 - 10160 10191 - 10358 10482 - 10524 10555 - 10597 10627 - 10669 10700 - 10742 10805-11095 11321 - 11654 3741 - 3735 3736 - 3752 3754 - 3763 3768 - 3769 3769 - 3769 3769 - 3768 3768 - 3767 3764 - 3747 3748 - 3770 1 2 ., DeDth TVD TVDe 522 521 NIPPLE 7370 3469 SLEEVE-C 7414 3478 Packer L2 7418 3479 SEAL 7433 3483 SBR L2 7446 3485 SHOE 7463 3489 HanoerL2 7732 3547 Packer L 1 7751 3551 SBR L 1 7777 3557 Hanoer L1 7784 3558 Hanoer ,",.. ----- Well Tvoe: INJ Odo Comoletion: 10/26/2004 Last w/o: Ref Loo Date: TD: 12607 ftKB Max Hole Anole: 95 deo @ 9632 , '. , TOD Bottom TVD Wt Grade Thread o 108 108 94.00 K-55 WELDED o 4197 2296 45.50 L-80 BTC o 8736 3725 29.70 L-80 BTC-M . :. . Size I TOD Bottom TVD Wt I Grade Thread 4.500 8569 11856 3788 12.60 I L-80 DWC . . . I Bottom I TVD I Wt I Grade Thread 7446 I 3485 I 12.60 I L-80 IBT . ' Zone Status Ft SPF Date TVDe Comment WS A2 122 40 10/8/2004 IPERF Slotted liner, 2.5" x .125" slots WS A2 62 40 10/8/2004 IPERF Slotted liner, 2.5" x .125" slots WS A2 330 40 10/8/2004 IPERF Slotted liner, slots every other 'oint Slotted liner, 2.5" x .125" slots Slotted liner, 2.5" x .125" slots Slotted liner 2.5" x .125" slots Slotted liner, 2.5" x .125" slots Slotted liner 2.5" x .125" slots Slotted liner, 2.5" x .125" slots Slotted liner, 2.5" x .125" slots Slotted liner, 2.5" x .125" slots Slotted liner, slots every other 'oint IPERF Slotted liner. 2.5" x 125' slots Port TRO Date Vlv Run Cmnt o 4/3/2005 o 4/3/2005 . Size 20.000 10.750 7.625 WSA2 WSA2 WSA2 WSA2 WSA2 WSA2 WSA2 WSA2 WSA2 84 251 167 42 42 42 42 290 333 10/8/2004 10/8/2004 10/8/2004 1 0/8/2004 10/8/2004 1 0/8/2004 1 0/8/2004 10/8/2004 10/8/2004 KRU 1 E-114 40 40 40 40 40 40 40 40 40 WSA2 73 40 10/8/2004 V Type V OD Latch ". ",' Anole æìJ TS: deo æìJ AnoleæìJTD: 84deoæìJ11857 Rev Reason: GL V desion Last Ucdate: 4/15/2005 IPERF IPERF IPERF ¡PERF IPERF ¡PERF IPERF ¡PERF IPERF 0.000 0.000 ,.,..,.., ID 3.875 3.810 5.500 3.875 4.750 3.875 5.500 5.500 4.750 4.500 4.750 . "".'." I ID I 5.500 I 5.500 ,....,. ..,. .... VMfr DMY DMY 1.0 BK-5 1.0 BK-5 DescriDtion CAMCO DB-6 NIPPLE BAKER SLIDING CMU SLEEVE - CLOSED 11/1/2004 ZXP LINER TOP PACKER FOR D-SAND L2 BAKER LOCATOR/SBE SEAL ASSEMBLY 190-47 CASING SEAL BORE RECEPTACLE FOR D-SAND L2 BAKER MULE SHOE LEM INSIDE HOOK HANGER FOR D-SAND L2 ZXP LINER TOP PACKER FOR B-SAND L 1 190-47 CASING SEAL BORE RECEPTACLE FOR B-SAND L 1 BAKER MODEL B1 FLANGED HOOK HANGER FOR B-SAND L 1 .EM ISIDE HOOK HANGER FOR B-SAND L 1 DeDth TVD TVDe 8570 3697 PACKER 8591 3700 HANGER éånåråln"ötåš .. .. Date Note 10/27/2004 TRI-LATERAL WELL w/A, B & D SAND LEGS 10/28/2004 TREE; ABB VETCO GRAY / HORZ/4-1/16" 5M TREE CAP CONNECTION: 9" OTIS DescriDtion HRD ZXP LINER TOP PACKER FLEXLOCK LINER HANGER E?~~~ ~~~~\"> ~'" \c...~ \\) " t"'\ ' " . Mr~ ~-\-~rþO,"âÇor- REL,E'VED STATEOFALASKA~~4.-~, " ALASKA OIL AND GAS CONSERVATION COMMISSION Æh!-1'J1UN O.:J L005 REPORT OF SUNDRY WELL OPERATION'&ska Oil & G~s GtÚ¡&. Comm¡~ ,(1 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 95' 8. Property Designation: Kuparuk Rver Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing structural CONDUCTOR SURFACE (45.5 è INTERMEDIATE LINER - A SAND Perforation depth: 5. Permit to Drill Number: 204-171 6. API Number: 50-029-23223-00 9. Well Name and Number: 1 E-114 10. Field/Pool(s): Kuparuk River Field I West Sak Oil Pool measured 11857' feet true vertical 3788' feet measured 11770 feet true vertical 6276' feet Length Size MD 108' 20" 108' 4102' 10-3/4" 4197' 8641' 7-5/8" 8736' 3287' 4-1/2" 11856' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2295' 3725' 3788' Measured depth: 8781-11789 true vertical depth: 3731-3781 Tubing (size, grade. and measured depth) .4-1/2', L-80, 7446' MD. RBDMS 8FL ,WN 0 (1 2005 Packers & SSSV (type & measured depth) no packer R\GINAL Form 10-404 Revised 04/2004 Submit Original Only . 1 E-114 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 4/20/200sICommenced Water Injection í· MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Red1' I{Zilc5 P.I. Supervisor ( DATE: Thursday, May 19,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-I 14 KUPARUKRIVUWSAK IE-I 14 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv aBf!- Comm NON-CONFIDENTIAL Well Name: KUPARUKRIVUWSAKlE-II4 API Well Number: 50-029-23223-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ0505I8073046 Permit Number: 204-171-0 Inspection Date: 5/17/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E-1l4 IType Inj. W ITVD I 3478 I IA 850 I 2000 1950 I 1950 I P.T. 2041710 ITypeTest SPT I Test psi i 869.5 lOA 450 i 450 500 I 500 Interval INITAL PIF P Tubing 0 I 0 0 I 0 Notes: 1 well house inspected; no exceptions noted. Thursday, May 19,2005 Page 1 of 1 . -" . . RECEIVED APR 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 ~ 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Convert to Injector Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 ~¡~a«S~~agons. Commissi( Change Approved Program 0 Opera!. ShutdownD 0 ~n rage Perforate Re-enter Suspended Wel 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 204-171/305-004 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-029-23223-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28',88' AMSL 1 E-114 8. Property Designation: 10. Field/Pool(s): ALK 25651, ADL 469 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11857' feet true vertical 3788' feet Plugs (measured) Effective Depth measured 11770' feet Junk (measured) true vertical 3780' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 4169' 10-3/4" 4197' 2295' INTERMEDIATE 8708' 7-5/8" 8736' 3725' LINER - A SAND 3231' 4-1/2" 11856' 3788' Perforation depth: Measured depth: slotted liner true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7446' MD. Packers & SSSV (type & measured depth) pkr @ 8570' SSSV= Landing Nipple 522' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation Pre-produced Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A jf C.O. Exempt: Contact Gary Targac @ 265-6586 Printed Name Randy Thomas Title Kuparuk Drilling Team Leader Signature \ c~, w~ Phone Phone: 265-6830 Date i.f/ll-lÓS- Prenared bv Sharon Al/suD-Drake 263-4612 , g/3 IJ~ ! I - . . Ii Form 10404 Revised 04/2004 '!II /l2- Submit Onglnal Only . . -.... . 1E-114 Well Events Summary . Date Summary 04/01/05 GAUGED TBG TO 2087' SLM WITH 3.8" GAUGE RING. ENCOUNTERED HYDRATES. IN PROGRESS. [Hydrates-Ice] 04/02/05 CLEAR HYDRATES WITH METHANOL, BRUSH, & G/R. GAUGED TBG TO 3.83" TO 7370' RKB. SET 3.812" DB PLUG (NO PACKING) @ 7370' RKB. PULLED DV @ 7070' RKB. IN PROGRESS. [GL V] 04/03/05 SET DV @ 4477' RKB. LOADED IA WITH INHIBITED SW & DSL CAP. SET DV @ 7070' RKB. MITIA 3000 PSI, PASSED. PULLED PLUG. [MIT] 04/05/05 MEASURED BHP @ 7843' MD: 1098 PSI. [Pressure Data] RECEIVED APR 2 1 2005 Alaska Oil & Gas Cons. Commission Anchorage . mn He IU¡ Ir ~..., 'ÍÌ' n.J , '\ r:\, J,.::!J . ~ tJ 1-(;,/7 I FRANK H. MURKOWSKI, GOVERNOR AI4ASIiA OIL Al'ft) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kuparuk 1 E-114 Sundry Number: 305-004 Dear Mr. Thomas: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a h . ay or weekend. A person may not appeal a Commission decision to Superior Urt less rehearing has been requested. DATED thisLiaay of February, 2005 Encl. . Conoc6Phillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 January 11, 2005 RECEIVED JAN 1 2 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission tmchorage Subject: Application for Sundry Approval for 1E-114, 1E-114L 1, 1E-114L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the West Sak wells 1 E-114, 1 E-114L 1 and 1 E-114L2. We are planning to pre- produce these wells. If you have any questions regarding this matter, please contact me at 265-6830 or Gary Targac at 265-6586. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad ORIGI~JAL · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25 280 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Alter casing 0 Repair well 0 Plug Perforations 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 2. Operator Name: 4. Current Well Class: ConocoPhillips Alaska, Inc. Development _ 0 3. Address: Stratigraphic 0 Perforate 0 o Stimulate OJ:) 2-/ (4($ h RECE;\IEtJti¿j; JAN 1 2 Z005 AL~' ,,) çß~ ê~'"<,,. f'hr." ~ nH.A"'H'~"", .J! """",,. " Waiver "r:l ..Mnular Disp. 0 M!1tf'itm.'Iyc Time Extension 0 Other 0 Pre-produce Re-enter Suspended Well o 5. Permit to Drill Number: 204-171 6. API Number: 50-029-23223-00 9. Well Name and Number: 1E-114 Exploratory 0 Service 0 P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28',88' AMSL 8. Property Designation: ALK 25651, ADL 469 11. Total depth MD (ft): 11857' Casing 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3780' MD TVD Burst 108' 108' Total Depth TVD (ft): Effective Depth MD (ft): 3788' 11770' Length Size CONDUCTOR 108' 20" SURFACE 4169' 10-3/4" INTERMEDIATE 8708' 7-518" LINER - A SAND 3231' 4-1/2" 4197' 8736' 11856' 2295' 3725' 3788' Perforation Depth MD (ft): slotted liner Packers and SSSV Type: pkr @ 8570' SSSV= Landing Nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randv Thomas __L~ I Perforation Depth TVD (ft): Tubing Size: 4-1/2" Packers and SSSV MD (ft) 522' January 21, 2005 Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Signature \ Phone: 265-6830 Conditions of approval: Commission Use Only N t'fy C .. h .. \,.).J t\\"tQO \:j L \..J o I ommlSSlon so t at a representative may witness ' 1 Collapse Tubing Grade: L-80 Tubing MD (ft): 7446' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Gary Targac @ 265-6586 Kuparuk Drilling Team Leader Date \. ( t( (oS- Sundry Number: rx:..L 30S- - 0.., ! Plug Integrity 0 BOP Test 0 Mechanical Integrity Test .~ Location Clearance 0 Other: ~,.\ ~ '\ l'-.. CoO ~'ts ~~\\~~~\r<\((:c\-\'~ \"- (''PÞr-¡: ~\\ ~ ~ û. \>-J'R- or t:"S:~~ T~ ~;>- t'--S'tf'. CCCO~ \J.Jj f\ \0 d.-\5 . ~ ~ \c ~ o-.~\. I[ ~\S(~ ð" S"""? L"rJ/b.( 0 RIG I N A L BY ORD~ 8Fl FEB 1 : :'~. /I,,{' ApprovedbŸ:7 /' rVV~ COMMISSIONER THE COMMISSION Date: Y/ J ,~/ ~ '-' V I ! Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate . . ::IG R£LE;.S::: ~'"Eli NUMBER ð04- \~ \ -" \") ) -- l J3 (? :\- 1: \J'...J~S\ S<:.'l \ e- \''-\\~ L\..\-L~ MECHANICAL INTEGRITY REPORT- '.. =:?UD DÞ.;:~: : OPER & FIELD Ca.s ing: ~5{C6 .:....:":ïe!:' : t\J ~ _:JD!.Z':g: l.\\/d Packer '6.5'ìOHD TVu¡ See ê.~ '(L\4\o :':ole Size C.1:'l/" ê.nå ¡ Perfs ~ O\-\-to \o\tX4.\·~ ""ok pa.c\.ar"\",:> ð~Ct ~<\- ·\k Y\.. +0b '\í'-~ ðu<3. .\0 (t Lt:. \'1'( Q:.S;\,) l~t"\.~"," \- :-SC?.ÞllIC;'-L INTEGRITY - P.4.RT /1 TD : . MD.. TVD¡ ?BTD: MD TVD Shoe: ~'ì()~ HD ?:) - DiI: \J~ HI) ·TVL> ::> ):s TVD i Shoe: MD TVD j ~,",T' HD :''¡j) ~~'r : ~~LL DATA ¡ 15 m~n ; 30 min Annulus Press Test: ~p COü:.i:8ents: r-- :-Œ CH../L?I11 CAL INTEGRITY - PART ¡ 2 Cement: Volumes :-. ÞJllt. Liner~; Csg~G bb\> j DV \.:J ~ C¡¡¡t -"01 to cover peris <6% b.~\~O\.C((.M€'V\..\·\â<...c"'!Ò~~'~~ o~\N,> \) ~l~\ '~s;ro( Q\\{)~\("-f.. ~O¿a 'f..S ~ ¡ Tb.eoret:ical Toe ú\~~'"'t"'C 'S\:Jt..ö Y. ~ ~~~> ~'c.a'\ \0<:: '~ '-l~O \ .) ¡Of'", -0'-\ .....J Cement Bond Log (Yes or No) "-JV::...> ; In AOGCC File '\(~ _ . ...\-\...to~S~. ~ t~'\ t - \ l -~J' . CBL !:.valuat~on, zone ê.~è-iJ-et£-s-~~\- MCì.~ ~ \jù~'CDb\.f (~t'\~~' 'ö.t\'"'\.\-a-co."c--.~\~~\r"" \o..~:s.. ~~'\ ~\t.<"_(),~'ð \"'~-.J' \.\-ð-'-~~b.. V l\ - . '.,.....". , . . . D - '\. .'~ \.' ~'.. . ~~ Proåuc..tian Log: Tn>e ¡Evaluation ~ (\Q:.\ +--~ \' . ~~ örW~\-\~, CONCLUSIONS: ? ar t: f 1 : ? ar:: : 2 : \-'\.¡::-~ r,k\",. ~~ -;;.< -0 S- -- I A L1' I \Lt - . . Tom, ,',' Here is the well orientation plot for the 1320 requested ~#..,¡'tl4. Also, included are the cementing reports for each one of these wells. Six wells were seen to intersect the 1320 plot: 1E-168 v :.) Ò,,-\ - ')()Ù f\ c 1E-123/ ;Jù'-\-G~ \ ,,"I(:~Q\~~J :sf~-o~ 1D-116../ \~'6- \ 'l J 1D-113 v ~~~ _ \''\. ~ 1D-112 j. '<1.. <is-- \<6~,. c 1D-103 ' ,~'?-OqC -<è,^,.\~<:ç\~J '1/(S-O~ All the wells had good cementing operations with the exception of 1D-103. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and perfonned a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 T~'-'\5 ,~ec..0It-'\...c."\- ~ÛL,,,, ~DS-\: c\ -\ ~ ~~\«£\. o.~7S~s~x-d, -\6\" ~"L\ \:[ .~, \C:-\\~ t-L~ç;!- L)~ \~t \:i.J'\ '0\2J\J~ \ ~\\... ~CD':~ ~ ",. \.,,<..U'- ç' \O-dE'ö\ "- '\-\r-e ~S.F~'-'G .ç~ \ ~. '" ~,t \ ~ \\.~ \J"-J c,<r,CJQ. ~Y-¡,~\ri:Od 0-\-0 \--.o-..JE- o.cœp\-ù..1Þ \<& \ ù'..:\F':f'~ ~ ' ~9-~~ ~ ;9-{ l ~OJ D .- 700~ / / ANTI~ÇQLUSION·SETfINGS 3538 3598 lnte.rpolatJwlMetû¡)d:TVD Depth Rallgl' Fro.rn-: ...3418.000 Maximum Rang~~ 1316.200 6000 5000 4000 ~ 3000 1000 I I 5000 W est( - )/East( +) [1000 ftlin ] 8000 -2000- RE: [Fwd: CD 1-11 Request to Commence Injection] , ø Subject: RE: [Fwd: CD 1-11 Request to Commence Injection] From: "Targac, Gary" <Gary.Targac@conocophillips.com> Date: Thu, 20 Jan 200507:54:58 -0900 To: Thomas Maunder <torn _ maunder@admin.state.akus> Tom, I'm working the issue wI Randy and Jerome. Probably not starting injection on 114 until mid-feb but will try and get you the data next week. Gary -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, January 13, 2005 5:18 PM To: Targac, Gary Subject: [Fwd: CD1-11 Requestto Commence Injection] Gary, I hope you don't take this wrong, but I am going to need you or some else there to do some "homework/legwork" on your requests for IE-114, et al. I am forwarding you a copy of what Alpine is doing with their injectors. For IE-114, we have discussed the cement log. You and I are in agreement that some sort of survelience log will be run. The main thing that needs to be done is the determination of the wells in the "1320"circle.from the top of the L2 window to the toe ofthe motherbore. Any well that penetrates the West Sak within that distance along the well path needs to have an assessment done on the production casing cement job. Assessment does not mean a bond log, it means an evaluation of how the job went and if it is likely that the objectives were met. Have a look at this message and the attachment and get back to me. Thanks in advance. Torn Maunder, PE AOGCC -------- Original Message -------- Subject:CDl-ll Request to Commence Injection Date:Wed, 12 Jan 2005 17:38:01 -0900 From:Hanson, Kelli L <Kelli.L.Hansonca)conocophiHips.com> To:tom maunderCá?admin.state.ak.us, bob fleckenstein(a),admin.state.akus, iim regg(a;admin.state.akus CC:Pierson, Chris R <Chris.R.Pierson(a?conocophillips.com>, Alonzo, Chris <Chris.AlonzoCa;conocophillips.com>, Schneider, Tim S. <Ti m. S. Schnei den?i;conocophillips,com> Mr. Maunder, lof2 1/27/20053:39 PM RE: [Fwd: CDI-II Request to Commence Injection] , , CPAI requests approval to commence injection into CDl-ll. The CDl-ll SCMT log is attached. The log indicates good quality cement is present across the logged interval from 12,098 MD (6,881' TVD SS) up to the tubing tail at 11,576' MD (6,724' TVD SS). The packer is located at 11,505' MD (6,692' TVD SS) @ 62.7 deg. The top of the Alpine C sand is located at 12,150' MD (6,889' TVD SS) @ 82 deg. The 7" casing shoe is located at 12,293' MD (6,904' TVD SS) @ 86 deg. PBTD is located at 15,057' MD (6,928' TVD SS) @ 85 deg. Placement of the cement job went as planned with good returns: Description of the 7" casing cement job pumped on 11/2/04: PJSM. Dowell pumped 5 Bbls. CW 100. Tested lines to 3700 PSI. Pumped 55 Bbls CW 100 @ 4.5 BPM 500 PSI and dropped bottom plug. Pumped 50 Bbls. Mud push XL 12.5 PPG @ 4.5 BPM 450 PSI. Followed by 53 Bbls. Lite Crete mixed at 11 PPG. and 24 Bbls. of Dowell INTER mixed at 15.8 PPG. Pumped at 4.5 BPM 500 PSI. Dropped top plug and Dowell pumped 20 Bbls. water. Switched to Rig Pump and displaced with 447 Bbls. 9.7 PPG mud at 4.5 BPM bumped plug and CIP @ 1830 Hrs. 11/2/04. Floats held and had good returns. The tubing and casing were successfully MIT'd on 11/7/04 as documented below: Rigged up lubricator and dropped rod/ball. Tested lines to 4500 PSI. Pressured tubing to 4200 PSI and set packer. Tested tubing to 4200 PSI for 30 Min. Bled tubing to 700 PSI and tested annulus to 3500 PSI for 30 Min. Bled Annulus to 0 and left 700 PSI on tubing. Based on this information I've concluded the Alpine interval is adequately isolated in CDl-ll. We would like to place this well on injection as soon as possible. Your early attention to this request would be appreciated. Thanks, Kelli «CD1-11_1320 Alpine disposal.pdf» «CD1-11_SCMT.zip» «rev CD1-11 Tbg detail.xls» «MIT CD1-11 11-7-04.xls» «CD1-11_State.ppt» Kelli L. Hanson Production Engineer Alpine Engineering WNS Subsurface Development 907.265.6945 20f2 1/27/20053:39 PM Re: [Fwd: Re: usn evaluation lE-114] . , Subject: Re: [Fwd: Re: USIT evaluation lE-114] From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 13 Jan 2005 07:44:33 -0900 To: "Targac, Gary" <Gary.Targac@conocophillips.com> , You have that correct. The other key is what the isolation is of the surrounding wells. I have a draft of that letter to Jim Hand on the integrity issues that I need to finalize. Changing to MI/gas will need to be closely evaluated. As I remember the presentation, water is all that is planned especially where there was some suspicion regarding the integrity of the "old" wells. We will no doubt be in touch as the maturity ofEOR operations in WS continues. Tom Maunder, PE AOGCC Targac, Gary wrote: I haven't seen the log but I think some type of logging to confirm isolation is prudent. Especially if we want to utilize lean gas injection for tertiary methods in the future. Gary -----Orig i na I Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Thursday, January 13, 2005 7: 18 AM To: Targac, Gary Subject: Re: [Fwd: Re: USIT evaluation 1E-114] Thanks Gary. Yeah, the weather has been nasty. So far this seems to be some of the most steady "winter" they have seen in a long time. On lE-l 14, based on the email trail I have it appears that a temperature log was discussed for it as well. Have you looked at lE-114's log?? Tom Targac, Gary wrote: Tom, the well we discussed the WFL was lE-112. Gary p.s. - After numerous weather delays, we should be starting water injection today on lE-112 and 1E-104. -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Thursday, January 13, 2005 7:01 AM To: Targac, Gary Subject: [Fwd: Re: USIT evaluation 1E-114] Gary, I am looking at some items on lE-114. Was this the well we discussed with regard to running a water flow log rather than a temperature log?? Thanks, Tom Maunder, PE AOGCC -------- Original Message -------- Subject:Re: USIT evaluation lE-ll4 lof3 2/11/2005 4:49 PM . ConocJPhillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 November 17, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 2,~ 2004 Subject: Well Completion Reports for 1 E-114, 1 E-114L 1, 1 E-114L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk wells 1 E-114, 1 E-114L 1 and 1 E-114L2. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, \~_...~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad OR\G\NAL . STATE OF ALASKA . ALA Oil AND GAS CONSERVATION COM ' ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 11·' 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 Suspended 0 WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other XXX Pre-Produced Injector Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: October 26, 2004 204-171 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 September 25, 2004 , 50-029-23223-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: , Surface: 91' FSL, 227' FEL, Sec. 16, T11 N, R10E, UM October 6, 2004 1E-114 At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 1885' FSL, 149' FEL, Sec. 15, T11N, R10E, UM 28' RKB /88' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 321' FNL, 94' FEL, Sec. 15, T11N, R10E, UM 11770' MD 13780' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 550301 ' y- 5959681 Zone- 4 , 11857' MD I 3788' TVD ALK 25651 TPI: x-555642 y- 5961512 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 555670 , V- 5964586 Zone- 4 Landing Nipple @ 522' ADL 469 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of NIA feet MSL Permafrost: 5765' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 335 sx AS I 10.75" 45.5# L-80 28' 4198' 28' 2295' 13.5" 730 sx AS Lite, 207 sx DeepCrete 7.625" 29.7# L-80 28' 8736' 28' 3725' 9.875" 515 sx DeepCrete 4.5" 12.6# L-80 8625' 11856' 3706' 3788' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 7446' 8570' t· '/ ,. slots in liner from 8781,'- ~903', 9027'-9089', 9120' e-ye~ other 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. jt to 9450',9576'-9660',9909'-10160',10191'-10358',10482'- DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10524',10555'-10597',10627'-10669',10700'-10742', n/a ~ ..., ..¡ t -t 10805'-11095,11321' every other jt to 11654', 1716'-11789' slots are 40 slots/ft 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) November 13, 2004 Pre-produced injector - production shared with 1 E-114L 1 and 1 E-114L2 Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS·Oll RATIO 11/17/2004 7 hours Test Period --> 368 166 5 45 Bean 517 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 398 psi 1366 24-Hour Rate -> 1222 611 18 n/a 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". i'···::·,c·:·:::;·:~':';:;:¡·l :;, ~,;ur ;'!~/t._t:,_\ tv:: ~ ~ IJ~\Ti ": NONE ' ~ò~ J, ..j.O.J". ..:.- I RBDMS BFL NOV 2 6 2004 \ .__~J5D -J ("11\1 ^ I !;¡"._-,..-....."'_._~ (;P nnl Form 10-407 Revised 12/2003 CÐNrlNÙED ÒNRËVERSt'"\ L 28. 29. . FORMATION TESTS GEOLOGIC MARKERS 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 E-114 West Sak A2 West Sak A2 West Sak A2 8775' 9894' 11302' 3731' 3735' 3747' NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 ne Kuoaruk Drillino Team Leader Lb~ -6'-850 1(/CCf (0 'r Signature Title: Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 Legal Well Name: 1E-114 Common Well Name: 1E-114 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 9/25/2004 00:00 - 02:00 2.00 MOVE RURD MOVE 02:00 - 08:00 6.00 MOVE MOVE MOVE 08:00 - 13:00 5.00 WELCTL NUND RIGUP 13:00 - 16:00 3.00 DRILL RIRD SURFAC 16:00 - 20:00 4.00 DRILL PULD SURFAC 20:00 - 20:30 0.50 WELCTL BOPE SURFAC 20:30 - 21 :30 1.00 DRILL PULD SURFAC 21 :30 - 22:00 0.50 DRILL CIRC SURFAC 22:00 - 00:00 2.00 DRILL DRLG SURFAC 9/26/2004 00:00 - 00:45 0.75 DRILL DRLG SURFAC 00:45 - 03:30 2.75 DRILL TRIP SURFAC 03:30 - 17:30 14.00 DRILL DRLG SURFAC 17:30 - 20:00 2.50 DRILL TRIP SURFAC 20:00 - 22:00 2.00 DRILL TRIP SURFAC 22:00 - 00:00 2.00 DRILL DRLG SURFAC Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Tear out & rig down for rig move. Move rig from 1 E-166 to 1 E-114, Rig up & Connect all Air, Mud, Steam, Water & Pump lines. Accept rig @ 08:00 hrs 9/25/04, Nipple up Diverter system, Mix Spud mud, Load pipe shed w/ 5" drill pipe & HWDP. Change out all surface equip., Iron Roughneck & Top drive saver sub from 4" to 5". Pick up 34 stands 5" drill pipe, 29 jts 5" HWDP & Jars and stand back in derrick. Function test Diverter system- OK, Test waived by AOGCC Jeff Jones. Make up BHA #1, Pick up 3 NMDC's, RIH & tag btm of conductor @ 108'. Fill conductor & check for leaks- OK. Note; Rig back on High line power at 21 :30 hrs 9/25/04. Spud well @ 22:00 hrs 9/25/04, Drill 13-1/2" hole f/1 08' to 220', ART= 1.6 hrs, 5/15K WOB, 60 RPM, 550 gpm @ 500 psi, UP 50K, DN 50K, ROT 50K, Torque on btm 2000 fUlb, Off btm 1000 fUlb. Drill 13-112" hole f/220' to 279' (59'), ART= 0.6 hrs, 5/20K WOB, 60/65 RPM, 550 gpm @ 600 psi, UP 50K, ON 50K, ROT 50K, Torque on btm 2000 fUlb, Off btm 1000 fUlb. POOH, Pick up Motor w/1.8 AKa & MWD for BHA #2, Orient same, RIH to 279'. Directional Drill 13-1/2" hole f/ 279' to 1,848' (1,569'), Ran 3 Gyro Surveys, ART= 0.5 hrs, AST= 8.9 hrs, WOB 10/20, RPM 70, 550 gpm @ 1900 psi, UP 92K, DN 76K, ROT None. PUMP out of hole to HWDP, POOH (No tight spots - Hole in good shape), Lay down Motor & clean rig floor. Pick up Motor w/1.3 AKa, Make up BHA #3, Orient same & RI H to 1,848', No problems going in hole. Directional Drill 13-1/2" hole f/ 1,848' to 2,040' MD /1,588' TVD (192'), ART= 0.8 hrs, AST= 0.6 hrs, WOB 10/20, RPM 80,590 gpm @ 2100 psi, UP 90K, DN 77K, ROT None, Torque 4/5000 fUlb on btm, 5000 fUlb off btm. Note; Camp off High line power from 09:30 hrs to 14:00 hrs due to CPF 1 Frame 6 maintainance. 16.50 DRILL DRLG SURFAC Drill 13-1/2" hole f/2,040' to 4,205' MD /2,298' TVD (2,165') (10-3/4" casing point), ART= 7.7 hrs, AST= 3.7 hrs, WOB 10/20, RPM 100, 700 gpm @ 2500 psi, UP 135K, DN 60K, ROT 88K, Torque 12K fUlb on btm, 12K fUlb off btm, Max gas 841 units. 1.50 DRILL CIRC SURFAC Pump Hi-vis weighted sweep & circ hole clean. 5.50 DRILL TRIP SURFAC Observe well, Backream out of hole 4,205' to 960' at drilling rate of 590 gpm @ 2300 to 1700 psi, RPM 100, Pulling pipe at rate of 40/45 fUmin., Had to slow down from 3,560' to 3530' & 3,360' to 3,330' due to torque and mild packing off, worked thru spots and cleaned up same, Lay down Ghost reamer. POOH on elevators & stand back HWDP. LD BHA #3, LD 3- 6 3/4" Flex DC's, MWD and Motor RU Doyons 103/4" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running casing MU 10 3/4" float shoe, 2 jts 103/4" 45.5# L-80, BTC csg, fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 2,072' (52 Jts) Circ btms up at 2,072', staged pump rate up to 6 bpm at 325 psi, st wt 9/27/2004 00:00 - 16:30 16:30 - 18:00 18:00 - 23:30 23:30 - 00:00 0.50 DRILL TRIP SURFAC 9/28/2004 00:00 - 02:00 2.00 DRILL PULD SURFAC 02:00 - 03:15 1.25 CASE RURD SURFAC 03: 15 - 03:30 0.25 CASE SFTY SURFAC 03:30 - 07:00 3.50 CASE RUNC SURFAC 07:00 - 08:30 1.50 CASE CIRC SURFAC Printed: 11/12/2004 11 :23:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: Sub Code Code Phase 9/28/2004 07:00 - 08:30 1.50 CASE CIRC SURFAC up 96K, dn wt 65K 08:30 - 09:15 0.75 CASE OTHR SURFAC Changed out rubber elements on Franks fill up tool 09:15 -13:00 3.75 CASE RUNC SURFAC Cont RIH with 103/4" csg, MU hanger and landed csg with float shoe at 4,198' MD/ 2,295' TVD, float collar at 4,112', no problems RIH, Ran a total of 79 jts (3,130') of 40.5# L-80, BTC csg above shoe track and a total 25 jts (1,032') of 45.5#, L-80, BTC csg including shoe track, total float equip, csg and hanger, 4,168', ran 15 bow spring centralizers and 1 stop ring per well plan 13:00 - 14:00 1.00 CEMEN CIRC SURFAC Circ btms up thru Franks fill up tool, staged pump rate up to 7 bpm at 600 psi, st wt up 190K, dn wt 65K 14:00 -14:30 0.50 CEMEN RURD SURFAC RD Franks fill up tool and MU Dowell's cement head 14:30 - 16:00 1.50 CEMEN CIRC SURFAC Fin circ and conditioning mud for cementing, final MW in & out, 9.3 ppg, 39 vis, 13 PV and 11 YP, circ at 7 bpm at 400 psi, st wt up 190K dn wt 70K, held PJSM with Dowell, APC vac truck drivers and rig crew on cementing operations while circ. 16:00 -18:15 2.25 CEMEN PUMP SURFAC Cemented 103/4" csg, Dowell pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 42 bbls of 10.5 ppg mudpush, began mixing and pumping Arcticset lead slurry, pumped 591 bbls (730 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 7 bpm at 180 psi, followed with 92 bbls (207 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.46 yield with add., ave 7 bpm at 300 psi, rE!lCl:iprøcatfJd csg til 17:45 hrs with 129 bbls lead cement out of shoe and had full returns, shut down and dropped top plug 18:15 -19:15 1.00 CEMEN DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 381 bbls of 9.3 ppg mud, displaced cmt at 7 bpm, initial circ pressure 550 psi, max pressure 725 psi, slowed rate to 3.5 bpm and bumped plug on calc displacement, pressured up to 1,300 psi, checked floats and held, CIP @ 19:15 hrs, had full returns during job and had 180 bbts of 10.7 ppg emt back to surface 19:15 - 20:00 0.75 CASE DEQT SURFAC Tested 103/4" csg to 3,000 psi for 30 min, good test 20:00 - 21 :30 1.50 CEMEN RURD SURFAC RD Dowell cement head and LD landing jt 21 :30 - 00:00 2.50 WELCTL NUND SURFAC ND 16" diverter line and began ND 21 1/4" diverter and spool 9/29/2004 00:00 - 01 :15 1.25 WELCTL NUND SURFAC Fin ND diverter and starting head, used crane to set out diverter and set in wellhead equipment 01 :15 - 03:00 1.75 WELCTL NUND SURFAC NU Vetco Gray 13 3/8" 5M MB 222 wellhead, tested seals to 5,000 psi for 15 min, installed test plug 03:00 - 05:00 2.00 WELCTL NUND SURFAC NU BOP stack 05:00 - 10:30 5.50 WELCTL BOPE SURFAC RU and tested BOPE, choke manifold, 4" and 5" flQOf valves, rams including 7 518" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, Jeff Jones with AOGCC waived witnessing of test 10:30 -11 :00 0.50 DRILL OTHR SURFAC Installed wear bushing 11 :00 -13:00 2.00 DRILL RIRD SURFAC Changed over top drive to 4" XT-39 DP, changed out saver sub, grabbers and pipe guide 13:00 - 18:30 5.50 DRILL PULD SURFAC PU and stood back 159 jts (53 stds) of 4" XT-39 DP 18:30 - 20:30 2.00 DRILL PULD SURFAC MU 9 7/8" BHA #4 with AutoTrak tool, initialized Autotrak and RIH to 1,077' with BHA #4, HWDP, jars and MU ghost reamer 20:30 - 23:15 2.75 DRILL TRIP SURFAC RIH from 1,077' to 4,048' with BHA #4 on 5" DP 23:15 - 23:30 0.25 DRILL SFTY SURFAC Discussed stripping drill procedure with crew on rig floor 23:30 - 00:00 0.50 RIGMNT RSRV SURFAC Began to slip and cut 100' of drlg line 9/30/2004 00:00 - 01 :00 1.00 RIGMNT RSRV SURFAC Fin slip and cut 100' of drlg line, serviced top drive and blocks 01 :00 - 06:45 5.75 CEMEN DSHO SURFAC RIH from 4,048', tagged plugs above float collar at 4,111', drilled out Printed: 11/12/2004 11 :23:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: Spud Date: 9/25/2004 End: 10/26/2004 Group: 9/25/2004 10/26/2004 5.75 CEMEN DSHO SURFAC plugs, float collar at 4,112', shoe track, float shoe at 4,198' and cleaned out to btm at 4,205', drilled 20' of new formation to 4,225' MD/ 2,301' TVD, 5-30K wob, 60-120 rpms, 500-600 gpm, 1,300 psi to 2,100 psi, rot wt 85K, up wt 140K, dn wt 55K Displaced out spud mud with clean 9.0 ppg LSND mud, evening MW in and out at 9.0 ppg, circ at 510 gpm, 1,700 psi and 30 rpm's RU and performed lOT to 12.Sppg EMW, 450 psi, 2,295' TVD with 9.0 PP9 MW Drilled 9 7/8" hole with AutoTrak tool per directional plan from 4,225' to 6,250' MD/3,049' TVD (2,025'), ADT 10.0 hrs, 3-15K wob, 130 rpm's, 600 gpm, off btm pressure 2,700 psi, on btm 2,800 psi, off btm torque 9K ft-Ibs, on btm 9K ft-Ibs with 2% lubricants, rot wt 93K, up wt 120K, dn wt 73K, clean hole ECD with 9.0 ppg MW at 500 gpm was 9.7 ppg, raised MW from 9.0 to 9.3 ppg at 6,000' per well plan, ECD with 9.0 ppg mud ave 10.1 ppg, ECD with 9.3 ppg MW ave 10.6 ppg, BGG with 9.0 ppg mud aye 175 units, max gas/conn gas ave 1,100 units, BGG with 9.3 ppg mud ave 100 units, max gas/conn gas aye 350 units 12.00 DRILL DRLG INTRM1 Drilled 9 7/8" Hole with AutoTrak tool per directional plan from 6,250' to 7,692' MD/ 3,539' TVD, (1,442') ADT 6.7 hrs, 5-15K wob, 130 rpm's, 600 gpm, off btm pressure 3,450 psi, on btm 3,500 psi, off btm torque 15K ft-Ibs, on btm 13K, rot wt 99K, up wt 165K, dn wt 65K, 9.3 ppg MW, aye ECD 10.8 ppg. Top of Ugnu "C" at 5,760' MO/2,841' TVD, Top of West Sak "D" at 7,457' MO/3,488' TVO, ave BGG 100 units, max gas 1,200 units 9.00 DRILL DRLG INTRM1 Drilled 9 7/8" Hole from 7,692' to 8,741' MD/3,721' TVD, (1,049') (75/8" Csg pt) ADT 5.2 hrs, 5-15K wob, 130 rpm's, 600 gpm, off btm pressure 3,600 psi, on btm 3,675 psi, off btm torque 17K ft-Ibs, on btm 13K, rot wt 97K, up wt 176K, dn wt 62K, 9.3 ppg MW, ave ECD 11.0 ppg, pumped weighted hi vis sweep with no increase in cuttings back Top of West Sak "a" at 7,777' MO/3,571' TVO, ave BGG 350 units, max gas 1,270 units Circ to clear BHA and downlink AutoTrak to ribs off Backream out of hole from 8,741' to 6,941', backreaming out at 130 rpm's, 600 gpm, 3,500 psi with no problems Backreamed out from 6,974' to 5,265' at 130 rpm's, 600 gpm at 2,400 psi, pumped out of hole from 5,256' to 10 3/4" csg shoe at 4,198' Pumped weighted hi vis sweep and circ hole clean, circ at 600 gpm, 2,350 psi, had 10% increase in cuttings back from sweep, circ add. btms up and clean at shakers, rot wt 89K, up wt 145K, dn wt 58K Monitored well at shoe-static POOH from 4,198' to 4,048', hole taking proper fill, pumped dry job POOH LD 5" DP from 4,048' to 1,071' to BHA, LD 96 jts of 5" DP Monitored well at BHA-static Serviced top drive and blocks Repaired pipe skate POOH LD 29 jts 5" HWDP and jars, cont to LD BHA #4, downloaded Autotrak tool and LD same, cleared rig floor and pulled wear bushing RU Doyon's 7 5/8" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of 7 5/8" csg RIH with 75/8",29.7#, L-80, BTC-M csg to 2,098', MU 75/8" Float shoe, 3 jts csg and float collar, thread locked btm 4 conn's and circ thru float equip and ck ok, RIH with 46 add. jts along with pup jts for spacing out to 2,098' 9130/2004 01 :00 - 06:45 06:45 - 07:30 0.75 DRILL CIRC SURFAC 07:30 - 08:15 0.75 DRILL LOT SURFAC 08:15 - 00:00 15.75 DRILL DRLG INTRM1 10/1/2004 00:00 - 12:00 12:00 - 21 :00 21 :00 - 21 :15 0.25 DRILL CIRC INTRM1 21:15-00:00 2.75 DRILL REAM INTRM1 10/2/2004 00:00 - 03:15 3.25 DRILL REAM INTRM1 03:15-04:15 1.00 DRILL CIRC INTRM1 04:15-04:30 0.25 DRILL OBSV INTRM1 04:30 - 05:00 0.50 DRILL TRIP INTRM1 05:00 - 07:45 2.75 DRILL PULD INTRM1 07:45 - 08:00 0.25 DRILL OBSV INTRM1 08:00 - 08:30 0.50 RIGMNT RSRV INTRM1 08:30 - 09:00 0.50 RIGMNT RGRP INTRM1 09:00 - 11 :30 2.50 DRILL PULD INTRM1 11:30 -13:30 2.00 CASE RURD INTRM1 13:30 - 14:00 0.50 CASE SFTY INTRM1 14:00 - 17:30 3.50 CASE RUNC INTRM1 Printed: 11/12/2004 11 :23:10 AM Legal Well Name: 1E-114 Common Well Name: 1E-114 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Sub Code 10/2/2004 17:30 - 18:30 1.00 CASE CIRC INTRM1 18:30 - 20:30 2.00 CASE RUNC INTRM1 20:30 - 21 :30 1.00 CASE CIRC INTRM1 21 :30 - 00:00 2.50 CASE RUNC INTRM1 Start: Rig Release: Rig Number: Spud Date: 9/25/2004 End: 10/26/2004 Group: 9/25/2004 10/26/2004 Circ a csg cap at 2,098', staged pump rate up to 4 bpm at 350 psi, st wt up 103K, dn wt 48K RIH with 75/8" csg from 2,098' to 4,126' Circ a csg capacity at 10 3/4" shoe, staged pump rate up to 4 bpm at 350 psi, st wt up 142K, dn wt 50K RIH with 75/8" csg from 4,126' to 5,072', RIH to 4,710', pumped down from 4,710' to 4,770', hadiof)UM csg down from 4, 77O't6 5,072', push&d 2 jts and would pump 3rd one doWn"st wtup 17OK, dn 35K, (block wt 35K) Total of 119 of 204 jts in hole 1.25 CASE RUNC INTRM1 RIH slow with 75/8" csg from 5,072' to 5,295' 0.75 CASE CIRC INTRM1 Circ btms up at 5,295', staged pump rate up to 5.5 bpm, 400 psi, st wt up 180K, dn wt 45K 6.75 CASE RUNC INTRM1 Fin RIH with 7 5/8" csg, RIH to btm slow due to excessive drag, MU hanger and landed 75/8" csg at 8,736' MD/3,725' TVD with float collar at 8,607', ran a total of 204 jts 7 5/8", 29.7#, L-80 BTC-M csg with 4-pup jts and hanger (Total 8,709'), ran 20 tandem rise cent, 40 bow spring and 24 straight blade centralizers per well plan, 1 every 30' 1.50 CEMEN CIRC INTRM1 Circ btms up thru Franks fill up tool conditioning mud for cementing, staged pump rate up to 6 bpm at 675 psi 0.25 CEMEN RURD INTRM1 LD Franks fill up tool and MU Dowell cement head 0.75 CEMEN CIRC INTRM1 Cont to circ and oond mud for cementing, circ at 6 bpm at 700 pst; st wt up 275K, dn 50K, initial MW out, 9.8 ppg, 156 vis, PV 31, YP 29, conditioned mud to final MW out of 9.3 ppg, 43 vis, 17 YP and 18 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ 1.50 CEMEN PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 40 add. bbls of CW 100, pumped 50 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 2168b1S; (615 sxs) of DeepCrete cmt at 12.5 ppg, 2.24 yield with additives, aYe 6 bpm at 250 psi, reciprocated pipe with full retums, shut down, washed up and dropped btm plug 1.50 CEMEN DISP INTRM1 Rig displaced cement with 9.3 ppg OBM, bumped plug on calc displacement after pumping 395 bbls OBM (95% pump eff.) ave 6 bpm while displacing cmt, max pressure 990 psi, slowed pump rate to 3 bpm with 30 bbls left to pump and bumped plug to 1,500 psi, ck floats and held CIP at 14:00 hrs, reciprocated pipe until CVY 1QO,was"QUtof shoe when hole began getting tight aoo stopped reciprocating, Calc TOC @ 5,500' Tested 7 5/8" csg to 3,000 psi for 30 min LD landing jt and RD csg equipment Installed 75/8" pack-off and tested seals to 5,000 psi for 15 min, installed wear bushing Changed out elevator bales and PU 6 3/4" BHA to rig floor PU and stood back in derrick 9 stds of 4" Hybrid push pipe MU 6 3/4" BHA #5,43/4" mud motor with 1.2 deg bend, MWD, LWD and PWD, oriented and uploaded MWD, RIH with BHA #5 to 283' Shallow tested MWD at 283', circ at 178 gpm at 550 psi, tool ck ok RIH with BHA #5 PU 4" XT-39 DP singles from pipe shed, RIH to 1032' Cont RIH with 6 3/4" BHA #5 PU 4" XT 39 DP from Pipe shed to 6,235', PU a total of 195 jts of 4" XT 39 DP RIH from 6,235' to 8,567' with 4" DP from derrick Slip and cut 65' of drlg line, serviced top drive and blocks RIH from 8,567' and tagged plugs above float collar at 8,606', drilled out 10/3/2004 00:00 - 01 :15 01 :15 - 02:00 02:00 - 08:45 08:45 - 10:15 10:15 -10:30 10:30 -11 :15 11: 15 - 12:45 12:45 -14:15 14:15-15:00 0.75 CASE DEOT INTRM1 15:00 - 16:30 1.50 CASE RURD INTRM1 16:30 - 18:00 1.50 WELCTL EORP INTRM1 18:00 - 19:00 1.00 DRILL PULD INTRM1 19:00 - 20:30 1.50 DRILL PULD INTRM1 20:30 - 23:00 2.50 DRILL PULD INTRM1 23:00 - 23:15 0.25 DRILL DEOT INTRM1 23:15 - 00:00 0.75 DRILL PULD INTRM1 10/4/2004 00:00 - 04:45 4.75 DRILL PULD INTRM1 04:45 - 05:45 1.00 DRILL TRIP INTRM1 05:45 - 07:30 1.75 RIGMNT RSRV INTRM1 07:30 - 08:45 1.25 CEMEN DSHO INTRM1 Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: From - To Hours Phase 10/4/2004 07:30 - 08:45 1.25 CEMEN DSHO INTRM1 float collar at 8,607', shoe trak and float collar at 8,736', drilled 20' of new formation from 8,741' to 8,761' MD/3,729' TVD, drilled with 0-15K wob, 50 rpm's, 236 gpm at 1,900 psi, rot wt 85K, up wt 140K, dn wt 55K 08:45 - 10:00 1.25 DRILL CIRC INTRM1 Circ hole clean for LOT, 9.35 ppg MW in and out, circ at 296 gpm, 2,600 psi and 50 rpm's 10:00 - 10:45 0.75 DRILL LOT INTRM1 RU and performed LOT to 14.7 ppg EMW, 1,030 psi, 3,729' TVD with 9.35 ppg MW 10:45 - 11:45 1.00 DRILL OTHR INTRM1 RU on 7 5J8"x 10 3/4" annulus with rig pump, pressured up to 3,500 psi and attempted to' break down annulus with no success, Note: on 10/3/04 had pumped 6 bbls down annulus 7 hrs after QP, At 16:00 hrs RU little Red and attempted to pump down annulus, after 2 hrs was able to pump 1 bbl into annulus, after next 2 1/2 hrs was only able to pump 0.8 bbl, shut down Little Red at 20:30 hrs 11:45 -18:15 6.50 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 8,761' to 9,321' MD/3,755' (560') ART 2.6 hrs, AST 1.2 hrs, 2-5K wob, 80-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,000 psi, off btm torque 6K, on btm 5.5K ft-Ibs, rot wt 85K, up wt 136K, dn wt 63K, clean hole ECD with 9.35 ppg OBM was 11.4 ppg, ECD while drlg with 9.35 OBM ave 11.5 ppg, ave BGG 250 units, max gas 517 units, Est top of West Sak A2 sand 8,769' MD/3,730' TVD 18:15 - 20:00 1.75 DRILL DEQT PROD Trouble shoot MWD due to poor decoding, adjusted flow rates and surged pipe and after surging pipe several times, tool began to pulse, no sweeps had been pumped when problem occured, earlier had bad decoding but was able to drill ahead 20:00 - 00:00 4.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 9,321' to 9,605' MD/3,738' (284') ART 1 hr, AST 1.1 hrs, 2-5K wob, 100-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,000 psi, off btm torque 6K, on btm 5.5K ft-Ibs, rot wt 84K, up wt 142K, dn wt 57K, 9.3 ppg OBM, ave ECD 11.4 ppg, ave BGG 250 units 10/5/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 9,605' to 10,475' MD/ 3,769' TVD (870'), ART 4.3 hrs, AST 2.6 hrs, 2-10K wob, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 2,900 psi, on btm 3,100 psi, off btm torque 6K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 85K, up wt 150K, dn wt 50K, 9.3 ppg OBM, ave ECD 11.45 ppg, ave BGG, 275-300 units 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 10,475' to 11,323' MD/ 3,748' TVD (848'), ART 3.3 hrs, AST 3.4 hrs, 2-15K wOb, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 170K, dn wt 48K, 9.3 ppg OBM, ave ECD 11.8 ppg, ave BGG, 275-300 units, max gas 425, began running push pipe at 11,274' 10/6/2004 00:00 - 07:00 7.00 DRILL DRLG PROD Directionally drilled 6 3/4" "A" sand lateral from 11,323' to 11,857' MD/ 3,788' TVD (534'), ART 3.8 hrs, AST .6 hrs, 2-15K wob, 120 rpm's, 75 spm, 318 gpm's, off btm pressure 3,500 psi, on btm 3,600 psi, off btm torque 7K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 98K, up wt 182K, dn wt 58K, 9.3 ppg OBM, ave ECD 11.9 ppg, ave BGG, 275 units, began running push pipe at 11,274' 07:00 - 08:45 1.75 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean, circ at 318 gpm, 3,600 psi and 120 rpm's, had no increase in cuttings from sweep 08:45 - 09:00 0.25 DRILL OBSV PROD Monitored well-static 09:00 - 13:30 4.50 DRILL REAM PROD Backreamed out of hole at drlg rate from 11,857' to 8,730' to 7 5/8" csg shoe with no problems, 120 rpm's, 320 gpm, 2,900 psi 13:30 - 15:00 1.50 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean, circ at 320 gpm, 2,800 psi and 80 rpm's, had no increase in cuttings from sweep, circ 3X Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: From· To Hours 10/6/2004 13:30 - 15:00 1.50 DRILL CIRC PROD btms up and clean at shakers, st up wt 140K, dn wt 65K 15:00 -15:15 0.25 DRILL OBSV PROD Monitored well-static 15:15 - 20:00 4.75 DRILL TRIP PROD POOH from 8,730' to BHA #5 at 252', SLM no corr 20:00 - 22:00 2.00 DRILL PULD PROD Stood back std of HWDP, jars and Flex DC's, download MWD and LD MWD/LWD and motor, cleared rig floor 22:00 - 23:15 1.25 RIGMNT RSRV CMPL TN Serviced top drive and drawworks while waiting on Schlumberger wireline, wireline unit was stuck behind rig move at KUP river bridge 23:15 - 00:00 0.75 WAlTON EQIP CMPL TN Waited on Schlumberger wireline unit, rig crew changed out air boot on riser, wireline unit arrived location at 00:00 hrs 10/7/2004 00:00 - 02:30 2.50 LOG RURD CMPL TN RU SchIum~Wireline. MU USIT logging tool with Welll.ec's tractor tool. Held PJSM with SWS and rig crew 02:30 - 07:00 4.50 LOG ELOG CMPL TN RIH with USIT bond log, RIH to 8,630' without having to turn tractor tool on, logged up to 3,000' and POOH, had~bc:Jnd, est TOC @ 3,250' 07:00 - 09:00 2.00 LOG RURD CMPL TN LD logging tools and RD Schlumberger, cleared rig floor 09:00 - 09:30 0.50 DRILL PULD CMPL TN MU BHA #6, 6 1/8" hole opener and RIH to 141' 09:30 - 13:00 3.50 DRILL TRIP CMPL TN RIH from 141' to 8,730' to csg shoe, est circ to fill pipe, 300 gpm, 2,000 psi, rot wt 84K, up wt 128K, dn wt 60K, 80 rpm's with 6.5K ft-Ibs torque NOTE: Rig and Camp off highline from 09:45 to 11 :30 hrs 13:00 - 15:00 2.00 DRILL TRIP CMPL TN TIH from 8,730' to 11,857', no problems RIH to btm 15:00 - 16:00 1.00 DRILL CIRC CMPLTN Circ hole clean with 9.3 ppg OBM, circ at 300 gpm, 3,000 psi, 120 rpm's, 6K ft-Ibs torque, rot wt 99K, up wt 160K, dn wt 60K 16:00 - 17:45 1.75 DRILL CIRC CMPL TN Changed hole over from 9.3 ppg OBM to 9.3 ppg solids free OBM, circ at 318 gpm, 2,850 psi, monitored well-static 17:45 - 20:15 2.50 DRILL TRIP CMPLTN POOH from 11,857' to 8,668', no problems or swabbing 20:15 - 20:30 0.25 DRILL OBSV CMPLTN Monitored well at shoe-static, dropped 1 3/4" rabbit on a wire 20:30 - 23:30 3.00 DRILL TRIP CMPLTN POOH from 8,668' to BHA #6 to 141' 23:30 - 00:00 0.50 DRILL PULD CMPL TN POOH, LD 2 jts of HT-38 HWDP and jars, LD 61/8" hole opener, calc fill on trip out 75 bbls, actual fill 86 bbls 10/8/2004 00:00 - 01 :15 1.25 DRILL PULD CMPLTN PU and stood back 9 jts of 4" XT-39 HWDP and cleared rig floor 01 :15 - 02:00 0.75 CASE RURD CMPLTN RU to run 4 1/2" liner and held PJSM with rig crew 02:00 - 05:00 3.00 CASE PULR CMPLTN PU and ran 4 1/2" liner per well program, ran 4 1/2" ROT silver bullet guide shoe with no float, 92 jts w/1-pup jt, (3,225') of 4 1/2" 12.6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 51 jts (1,591') of blank liner and 41 jts (1,634') of slotted liner, ran 1- 4 1/2" x 6 1/4" spiralglide centralizer 1/jt to csg shoe (86 total) ran 9 restrictor packers with 18 spacer rings placed on blank liner to isolate shale sections per geology. 05:00 - 06:00 1.00 CASE PULR CMPL TN MU Baker 190-47 csg seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 3,298' 06:00 - 12:00 6.00 CASE RUNL CMPL TN RIH with liner assembly to 8,719', (csg shoe) est circ at 4 bpm, 550 psi, then rotated liner at 10 rpm's with 5.5K ft-Ibs torque, rot wt 80K, up wt 115K, dn wt 62K, having to screw into each std to keep mud from running over 12:00 - 15:00 3.00 CASE RUNL CMPL TN Cont to run 4 1/2" liner in open hole, RIH from 8,719' and tagged btm at 11,857' with no problems, PU to 11,856', st wt up 163K, dn wt 70K 15:00 - 16:00 1.00 CASE OTHR CMPL TN Dropped 1 7/16" ball and pumped down to seat, pump at 4 bpm at 975 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, bled off the pressure, cont to set packer, pressured up to 4,200 psi and set ZXP packer, no problems setting hanger/packer, set,~A"$åAd liner WItt TOt.. @ 8;569' MD/3,696' TVD and shoe at 11,856', st wt up after setting liner 145K, lost 18K wt Printed: 11/12/2004 11 :23:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Hours Sub Code Code Phase 0.25 CASE 1.00 DRILL 0.25 DRILL 4.75 DRILL DEQT CIRC OBSV TRIP CMPL TN CMPL TN CMPL TN CMPL TN 22:15 - 00:00 1.75 WINDO CMPLTN 10/9/2004 00:00 - 02:30 2.50 WINDO PULD CMPL TN 02:30 - 03:00 0.50 WINDO CMPL TN 03:00 - 07:30 4.50 WINDO CMPL TN 07:30 - 08:15 0.75 WINDO CMPL TN 08:15-09:00 0.75 WINDO CMPLTN 09:00 - 10:00 1.00 WINDO CMPL TN 10:00 - 10:30 0.50 WINDO CMPL TN 10:30 - 15:15 4.75 WINDO CMPL TN 15:15 -16:00 0.75 WINDO CMPL TN 16:00 - 16:15 0.25 WINDO CMPL TN 16:15 -18:30 2.25 WINDO CMPL TN 18:30 - 20:30 2.00 WINDO CMPLTN 20:30 - 21 :30 1.00 WELCTL OTHR CMPLTN 21 :30 - 00:00 2.50 WELCTL BOPE CMPLTN 10/10/2004 00:00 - 01 :30 1.50 WELCTL BOPE CMPL TN 01 :30 - 02:00 0.50 DRILL OTHR CMPL TN 02:00 - 03:00 1.00 RIGMNT RSRV CMPL TN 03:00 - 06:00 3.00 DRILL PULD PROD2 06:00 - 09:15 3.25 DRILL TRIP PROD2 09:15 -10:15 1.00 RIGMNT RSRV PROD2 10: 15 - 11 :00 0.75 DRILL REAM PROD2 11 :00 - 00:00 13.00 DRILL DRLG PROD2 Start: Rig Release: Rig Number: Spud Date: 9/25/2004 End: 10/26/2004 Group: 9/25/2004 10/26/2004 RU & tested 75/8" csg and ZXP packer to 1,000 psi for 5 min, good test PU out of SBE 33' and circ btms up, circ at 7.5 bpm at 2,500 psi Monitored well-static POOH wet and LD Baker setting tool, SLM out, no corr, calc fill on trip out 59 bbls, actual fill 67 bbls, cleared ri floor Began MU whipstock assembly, PU whipstock and broke out btm trip anchor and LD whipstock, MU milling assembly and LD same, PU seal assembly, locator sub, 3 1/2" DP pup jt, unloader sub, then PU 10 jts 3 1/2" DP RIH to 327' with seal assembly Fin MU whipstock BHA #7, RIH from 327', PU a total of 24 jts of 31/2" DP for space out, 75/8" btm trip whipstock, milling assembly with MWD, oriented MWD and RIH with 3 stds 4" HWDP and 9 stds of 4" push pipe to 1 ,158' Shallow tested MWD and tool ck ok RIH with whipstock from 1,158' to 7,820' Made MADD pass from 6,970' to 7,000' (sensor depth) and correlated MWD to K-13 sand RIH with whipstock from 7,850' to 8,520' Oriented whipstock to 13 deg left of high side, RIH, tagged TOL at 8,569', set whipstock and sheared off from same, st wt up 137K dn wt 64K Displaced out 9.3 ppg solids free OBM with used 9.3 ppg OBM Milled window in 75/8" csg, tap of windoW at 7,778', btm of window at 7,790', drilled 6 3/4" hole to 7,809' MD (31'), 2-6K wob, 80-120 rpm's, 270-310 gpm, 2,800 psi, rot wt 85K, up wt 137K, dn wt 65K, 6-8K ft-Ibs torque Circ hi vis sweep and circ hole clean, circ at 310 gpm at 2,800 psi, worked mills thru window with no problem Monitored well-static, pumped dry job POOH from 7,809' to BHA #7 at 1,189', monitored well-static LD 3 jts of 4" HWDP, stood back 2 stds HWDP and 9 stds push pipe, LD MWD and milling assembly, upper mill was in gauge, cleared rig floor Pulled wear bushing and flushed out stack RU af1d began testing BOPE, tesöngYaWes, I'TII'mIfold and rams to 250 psi low and 3,500 psi 1UgtI, tesI.1Id annular to 250 psi low and 2,800 psi high. NOTE: John Crisp with AOGCC waived witnessing of test Fin. testing BOPE, valves, manifold and rams to 250 psi low and 3,500 psi high, Note John Crisp W/AOGCC waived witnessing of test Installed wear bushing Changed out 4" Xt-39 saver sub on top drive MU 6 3/4" BHA #8 with Autotrak tool and uploaded, PU std of flex DC's and MU std of XT 39 HWDP with jars RIH to 240' RIH with BHA #8 from 240' to 7,714', shall low tested MWD at 2,295' and ck ok Slip and cut 75' of drlg line, serviced top drive and drawworks RIH from 7,714', washed down from top of window at 7,778' to btm at 7,809', no problems going thru window Drilled 6 3/4" hole with AutoTrak tool in "B" Sand lateral from 7,809' to 9,000' MD/3,581' TVD, (1,191 '), ADT 8.4 Hrs, 5-15K wob, 120-150 rpm's, 75 spm, 318 gpm, off btm pressure 3,250 psi, on btm 3,325, off btm torque, 7.5K ft-Ibs, on btm 6.5K ft-Ibs, rot wt 83K , up wt 137K , dn wi 59K, 9.3 ppg OBM in hole, (clean hole ECD =11.4 ppg) ave ECD 11.7 ppg, ave BGG 260 units, max gas 482 units Printed: 11/12/2004 11 :23:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Hours Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 10/11/2004 00:00-01:15 1.25 DRILL DRLG PROD2 01 :15 - 02:15 1.00 DRILL DEQT PROD2 02:15 - 03:15 1.00 DRILL DRLG PROD2 03:15 - 03:45 0.50 DRILL CIRC PROD2 03:45 - 06:00 2.25 DRILL REAM PROD2 06:00 - 07:00 1.00 DRILL CIRC PROD2 07:00 - 07:15 0.25 DRILL OBSV PROD2 07:15 - 10:15 3.00 DRILL TRIP PROD2 10:15 - 11 :15 1.00 DRILL PULD PROD2 11:15-13:00 1.75 DRILL PULD PROD2 13:00 - 18:00 5.00 DRILL TRIP PROD2 18:00 - 21:15 3.25 DRILL DRLG PROD2 21:15-22:30 1.25 DRILL DEQT PROD2 22:30 - 00:00 1.50 DRILL DRLG PROD2 10/12/2004 00:00 - 00:30 0.50 DRILL DEQT PROD2 00:30 - 01 :30 1.00 DRILL REAM PROD2 01 :30 - 03:00 1.50 DRILL TRIP PROD2 03:00 - 04:00 1.00 DRILL CIRC PROD2 04:00 - 07:30 3.50 DRILL TRIP PROD2 07:30 - 08:15 0.75 DRILL PULD PROD2 08:15 - 09:15 1.00 DRILL PULD PROD2 09:15 - 10:15 1.00 DRILL PULD PROD2 10:15 - 12:00 1.75 DRILL TRIP PROD2 12:00 - 13:45 1.75 DRILL TRIP PROD2 13:45 - 14:30 0.75 DRILL REAM PROD2 14:30 -16:30 2.00 DRILL REAM PROD2 Drilled 6 3/4" hole with AutoTrak tool from 9,000' to 9,113' MD/3,582' TVD, ADT .5 hrs Trouble shoot AutoTrak tool, unable to get pressure to ribs, to attempt to drill ahead in hold mode Drill from 9,113' to 9,206' MD/3,583' TVD (93') ADT 1 hr, 5-15K wob, 150 rpm's, 318 gpm, on btm pressure 3,300 psi, off btm 3,300 psi, off btg torque 8K ft-Ibs, on btm 8K, rot wt 82K, up wt 136K, dn wt 63K, determined hydraulic seal on ribs of AutoTrak tool failed Downliked autoTrak to ribs off, got SPR's, monitored well-static Backreamed out from 9,206' to 7,714', backreamed out to above window at 7,778' at 120 rpm's, 318 gpm at 3,000 psi Circ hole clean at 318 gpm at 2,800 psi, 90 rpm's Monitored well-static POOH from 7,714' to 48' to AutoTrak tool, stood back HWDP, jars and flex Dc's, Downloaded AutoTrak tool and LD same MU BHA #9 with new AutoTrak tool, uploaded tool and RIH to 240' with flex dc's, jars and HWDP RIH from 240' to 9,116', washed 90' to btm at 9,206' with no problems RIH or going thru window Drilled from 9,206' to 9,580' MD/3,589' TVD (374') ADT 1.7 hrs Trouble shoot the ontrak survey package of AutoTrak tool, found the X-axis of the MAG package was bad, decided to drill ahead and survey eliminating X-axis Drilled from 9,580' to 9,673' MDI 3,590' TVD, (93') ADT 1.1 hrs, 5-15K wob, 150 rpm's, 318 gpm, off btm pressure 3,300 psi, on btm 3,300 psi, off btm torque 6.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 82K, up wt 135K, dn wt 56K, 9.3 ppg OBM, ave ECD 12.1 ppg, ave BGG 275 units, max gas 459 units. Note: Decision was made after taking survey that too much time would be required to get good survey, preparing to POOH and PU mud motor to drill lateral Trouble shoot the Ontrak survey package of the AutoTrak tool. Down link, ribs off. Take Slow pump rates, monitor well. Back ream out from 9,673' - 9,206' at 120 RPM and 315 GPM. POOH on elevators from 9,206' to 7,714' (pass thru window wlo problems). Circulate btms up at 75 SPM, 2,800 psi. Monitor well, pump dry job. POOH on elevators to 56', lay down stabilizer and float sub. Download MWD data, break bit, make service breaks, lay down AutoTrak and MWD. PU and MU Motor assembly, set AKO at 1.2 deg. Check connection torque on MWD/LWD and motor. Plug in and upload MWD. RIH to 2,584', shallow test MWD at 75 stks 1,759 psi, continue RIH to 3,892'. RIH to 7,723', orient toolface and pass thru window wlo problems. RIH to 8,564'. Wash and Ream from 8,564' - 8,844' at 60 SPM, 2000 psi, 40 rpm, 6,000 ft-Ib. Wash and Ream from 8,844' - 9,673' at 80 SPM, 2150 psi, 80 rpm, 7,000 ft-Ib. Took survey check shots at 9,218',9,311',9,405',9,498', 9,592'. Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 1 0/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: From - To Hours Sub Code Code 7.50 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/9,673' to 10,420' MD - 3,597' TVD ADT - 3.8 hrs. = ART - 3.2 hrs. AST - 0.6 hrs. WOB 2-8 RPM 120 GPM 318 wI 75 spm @ 3,125 psi String wt. PU 137 so 56 Rot 82 Torque on/off btm - 8,000 I 7,500 ft-Ib 12.00 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/10,420' to 11,460' MD - 3,592' TVD ADT - 6.2 hrs. = ART - 4.3 hrs. AST - 1.9 hrs. WOB 2-7 RPM 120 GPM 315 wI 75 spm @ 3,350 psi String wt. PU 165 SO 35 Rot 83 Torque on/off btm - 8,000 I 8,000 ft-Ib 2.25 DRILL DRLH PROD2 Drill horizontal B-Lateral section f/11 ,460' to 11,570' MD WOB 2-9 RPM 110-120 GPM 315 wI 75 spm @ 3,425 psi String wt. PU 166 SO 57 Rot 86 Torque onloff btm - 8,000 I 8,500 ft-Ib Downlink MWD/LWD. Decoding problem. Bump up mud pump dampner pressure to 1,000 psi. Drill ahead 11,570' - 11,630'. MWD was not decoding properly. Reduced dampner pressure to 750 psi and had no success. Reduced dampner pressure to 450 psi and down linked MWD. Drill horizontal B-Lateral section f/11 ,460' to 11,841' MD - 3,611' TVD ADT - 2.9 hrs. = ART - 2.0 hrs. AST - 0.9 hrs (for tower). WOB 2-9 RPM 120 GPM 315 wI 75 spm @ 3,425 psi String wt. PU 158 SO 60 Rot 92 Torque onloff btm - 9,000 19,000 ft-Ib Pump weighted HI-VIS sweep and circ out at 74 spm and 3,700 psi, 10 rpm. Monitor well - static. BROOH from 11,841' to 10,340' at drilling rate wlo probs. BROOH from 10,340' - 8,003', at drilling rate, wlo probs. Pull25K over at the hard spot 41' outside of the window. Oriented to 13L of high side and pulled 10-15K over thru hard spot. Worked up and down from 7,831 '-7,816' wlo pumps and pulled into the 7-5/8" csg. Pump 30 bbl weighted Hi-Vis sweep and circ clean at 75 spm and 2,300 psi. Orient to high side and monitor well. Trip in hole to 9,200' wlo problems. Wash and ream thru tight spots, and work thru 3 additional times. Cont. RIH to 11,841' TD wlo probs. CBU at 11,841' at 70 spm and 3,450 psi. Swap over to solids free OBM at 70 spm and 3,350 psi. Take slow pump rates, monitor well, POOH on elevators to 11,180'. POOH from 11,180' - 7,680' wlo probs. Monitor well above window - static. POOH on elevators from 7,680'-248'. Monitor well - static, Rack back HWDP, Jars, and NMCSDP. Download MWD. Break bit, LD Motor/MWD. PU whipstock retrieving tools, 1 jt 3-1/2" HWDP, F/S, Bumper sub and Oil Jars + 11 DCs. RIH to 7,790'. Wash whipstk slot and attempt to hook, turn 90 deg and wash, make several attempts. Hook whipstock, shear trip anchor, pull 80K over. Circulate btms up 1.5x at 50 spm and 1,200 psi. Monitor well, blow down Top Drive and POOH to 430'. Monitor well. 10/12/2004 16:30 - 00:00 10/13/2004 00:00 - 12:00 12:00 - 14:15 14:15 - 15:15 1.00 DRILL DEOT PROD2 15:15 -16:15 1.00 DRILL DRLH PROD2 16:15 -17:30 1.25 DRILL DEOT PROD2 17:30 - 20:00 2.50 DRILL DRLH PROD2 20:00 - 21 :45 1.75 DRILL CIRC PROD2 21 :45 - 00:00 2.25 DRILL REAM PROD2 10/14/2004 00:00 - 03:45 3.75 DRILL REAM PROD2 03:45 - 04:15 0.50 DRILL TRIP PROD2 04:15 - 05:30 1.25 DRILL CIRC PROD2 05:30 - 05:45 0.25 DRILL OBSV PROD2 05:45 - 08:30 2.75 DRILL TRIP PROD2 08:30 - 09:30 1.00 DRILL CIRC PROD2 09:30 - 11 :00 1.50 DRILL CIRC PROD2 11 :00 -12:00 1.00 DRILL OBSV PROD2 12:00 -14:15 2.25 DRILL TRIP PROD2 14:15-17:00 2.75 DRILL TRIP PROD2 17:00 - 18:30 1.50 DRILL OTHR PROD2 18:30 - 20:30 2.00 CMPL TN PULD CMPL T2 20:30 - 23:00 2.50 CMPL TN TRIP CMPL T2 23:00 - 00:00 1.00 CMPL TN OTHR CMPL T2 10/15/2004 00:00 - 00:30 0.50 CMPL TN OTHR CMPL T2 00:30 - 02:00 1.50 CMPL TN CIRC CMPLT2 02:00 - 07:00 5.00 CMPL TN TRIP CMPLT2 Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 10/15/2004 07:00 - 08:30 1.50 CMPL TN PULD CMPL T2 08:30 - 09:45 1.25 CASE PULR CMPL T2 09:45 - 10:00 0.25 CASE SFTY CMPL T2 10:00 - 12:00 2.00 CASE RUNL CMPL T2 12:00-13:15 1.25 CASE RUNL CMPL T2 13:15 -13:45 0.50 CASE RUNL CMPLT2 13:45 - 16:30 2.75 CASE RUNL CMPL T2 16:30 - 21:30 5.00 CASE RUNL CMPL T2 21 :30 - 00:00 2.50 CASE RUNL CMPL T2 10/16/2004 00:00 - 00:30 0.50 CASE RUNL CMPL T2 00:30 - 02:00 1.50 CASE RUNL CMPL T2 02:00 - 06:00 4.00 DRILL TRIP CMPL T2 06:00 - 10:00 4.00 RIGMNT RGRP CMPL T2 10:00 - 10:45 0.75 CASE PUTB CMPL T2 10:45 -11 :00 0.25 CASE SFTY CMPL T2 11 :00 - 12:00 1.00 CMPLTN PULD CMPL T2 12:00 - 13:00 1.00 CASE PULR CMPLT2 13:00 - 17:30 4.50 CASE RUNL CMPLT2 17:30 - 20:00 2.50 CASE RUNL CMPLT2 20:00 - 00:00 4.00 CASE OTHR CMPL T2 10/17/2004 00:00 - 02:45 2.75 CASE OTHR CMPL T2 02:45 - 04:30 1.75 CASE RURD CMPL T2 04:30 - 05:00 0.50 CASE RURD CMPL T2 05:00 - 06:00 1.00 CASE RURD CMPL T2 06:00 - 08:00 2.00 RIGMNT RSRV CMPLT2 08:00 - 12:00 4.00 WELCTL BOPE CMPLT2 12:00 - 12:30 12:30 - 14:30 0.50 WELCTL BOPE CMPL T2 2.00 CASE RURD CMPL T2 Start: Rig Release: Rig Number: Spud Date: 9/25/2004 End: 10/26/2004 Group: 9/25/2004 1 0/26/2004 LD Jars, Bumper sub, Retrieving tool, whipstock, 9x 3-112" DP, Trip anchor, 13 x 3-1/2" space out DP, seal assembly. Clean rig floor, LD Baker tools, PU casing tools and RU to run liner. PJSM wI Company Rep, rig crew, csg hand for running 4-1/2" liner. PU/MU bent 3-1/2" bent joint with Baker guide shoe, packoff bushing. RIH wI 2,522' of 4-1/2", 12.6 Iblft, L-80, DWC blank I slotted liner with 32x 2.5" x 0.125 slots/ft with 4 circumfrential adjacent rows, staggered 18 degrees. Restrictor packers at 11,516' and 11,255', with blank liner joints between. Spiraglider centralizers (4-1/2" x 6-114"), free floating - 1 per joint, on joints #3 - #126. Average MU torque for liner was 6,300 ft-Ib. Run a total of 128 liner joints, MU Baker 7-5/8" x 4-1/2", Model B1 Flanged Hook Hanger, with hanger running tool. RD casing equipment. MU liner hanger and RD casing equipment RIH on DP to top of window at 7,778'. Orient and make 5 attempts to get bent joint through the window. PU and rotate on each pass. RIH to 11,771' and prep to hook the hook hanger. UP=155K, DWN=75K. RIH to 11,803', pass thru window and RIH an additional 1 0'. PU and hook hanger. Unhook and rehook to verify. Drop ball and pump down at 4 BPM and 1,000 psi. Seat ball and pressure up to 3,000 psi to release. PU to verify, was not released. Re-hook hanger and pressure up to 4,000 psi. PU to verify, not released. Re-hook hanger. RU test pump, and pressure up to 4,600 psi~ relea~ frQIDhanger. Note: pinned for 2,500 psi. Blow down TD, POOH, make service breaks, LD liner running tool. Change out upper IBOP valve on Top Drive, test to 3,500 psi. RU casing equipment, clear rig floor. PJSM for running 4-1/2" liner. PU Baker seal assembly. RIH with 10 jts 4-1/2:, 12.6Ib/ft, L-80 tbg. Continue to MU LEM assembly. RIH with LEM assembly on DP to 8,602' Attempt to stab into seal bore receptacle without success. Work pipe setting down 25K, and PU without any drag. POOH with LEM assembly. Continue POOH with LEM assembly. LD LEM, rack back 7 stds of 4-1/2" tbg in the derrick. RD casing equipment, clean rig floor, PU Baker Fishing tools, double stacked tubing tongs. MU Baker reverse circulating basket with 3-3/4" shoe. Cease RU fishing assembly after receiving confirmation of toollD restriction in the profile of the ZXP packer. Make service breaks, RD Baker fishing tools and power tongs. PJSM, Slip and Cut 97' of drill line. Service Top Drive and drawwork brakes. Pull Wear Bushing. RU and tested BOPE, chw manifold, 4" and 5" floor valves, rams excluding btm 7-618" csg·rame to 200 psi low and 3,500 psi high, annular t0250 psi Jow .nd,3,500pei..Teete6 ~ alarm system. Jeff Jones with AOGCC waived witnessing of test Install WB. PJSM and MU LEM assembly. Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/17/2004 Date From· To 14:30 - 19:00 'V 10/18/2004 À.~ r:v \ <:¿, /"\ 1 0/19/2004 1 0/20/2004 1 0/21/2004 19:00 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 04:15 04:15 - 08:30 08:30 - 09:30 09:30 - 09:45 09:45 - 10:30 10:30 - 12:00 12:00 - 15:00 15:00 - 16:00 16:00 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 01 :30 01:30-02:15 02:15 -12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 03:00 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 4.50 CASE RURD CMPL T2 0.50 CMPL TN PCKR CMPL T2 0.50 CMPL TN OEQT CMPL T2 1.00 CMPL TN CIRC CMPL T2 3.00 CMPLTN TRIP CMPLT2 1.00 CMPL TN PULD CMPL T2 PULD CMPL T2 0.25 WINDO 0.75 WINDO 1.50 WINDO 3.00 WINDO 1.00 WINDO 4.00 WINDO 0.50 WINDO 0.50 DRILL 1.00 DRILL 2.00 DRILL 1.50 DRILL 0.75 DRILL 9.75 DRILL 12.00 DRILL CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 CMPL T2 PROD3 PR003 PROD3 PR003 PROD3 PR003 DRLH PROD3 12.00 DRILL DRLG PROD3 12.00 DRILL DRLG PROD3 3.00 DRILL DRLH PROD3 RIH with new space out joint and seal assembly +LEM I ZXP pkr assembly, on DP to 8,610'. UWT= 145K, DWT=85K. Drop 1-3/4" ball, and pump down at 4 BPM. Set 40K Ib down and pressure up to 3,500 psi and pressure bled back to +1- 2,000 psi, bumped pressure back up to 3,500 psi seUing down 40K. The drill string moved down +/- 3'. Set packer. Close Annular preventor, test and chart liner top pkr to 1,000 psi for 5 min. - okay. Bleed off. Circ btms up at 7,625' and monitor well. POOH to 310'. Finish POOH, LD LEM running tools (no damage seen). Clean rig floor. MU mill assembly, whipstock, seal assembly, 3 joints 3-1/2" HWDP, trip anchor, MWD, Bumper Sub, Oil Jar. Orient whipstock to MWD. RIH, PU 3 joints of 4" HWOP, to 1,824'. Shallow test MWD. Cont. RIH to 7,289', Log K-13 sands 7,289' - 7,309'. RIH to 7,709', orient whipstock 10L deg of high side. UWT=135K, DWT= 63K Set whipstock, shear off. Displace solids free OBM to treated 9.3 ppg drilling OBM fluid. Mill window from 7,465' ROT=80K, Torque on = 5-8,000 ft-Ib. Continue milling window tô7,489' Note: TOW=7,465', BOW=7,479'. Pump Hi-Vis sweep, circ hole clean, monitor well. POOH. Wash out stack and clean rig floor. PU/MU bit, 1.2 deg motor and MWO. Upload MWD and orient. RIH with 6-3/4" motor + MWD drilling assembly to 3,708'. Continue RIH fl 3,708' to 7,445'. Orient thru window @ 7,465' to 7,477', Wash & Ream down to 7,489' Drill 6-3/4" Lateral '0' Section f/7,489' to 8,230' MD 3,513' TVD (741'), ART 3.8 hrs, AST 1.8 hrs, UP 120K, DN 60K, Rot 80K, 315 gpm @ 2450 psi, 2/15K WOB, 120 RPM, Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.4 ppg, Max gas 234 units. Drill 6-3/4" Lateral 'D' Section fl 8,230' to 9,357' MD 3,538' TVD (1,127'), ART 6.7 hrs, AST 1.4 hrs, UP 135K, DN 55K, Rot 80K, 315 gpm @ 2550 psi, 5/15K WOB, 90/120 RPM, Ave ECD's 11.5 ppg, Max gas 285 units. Drill 6-3/4" Lateral '0' Section f/9,357' to 10,432' MD, 3536' TVD (1075'), ART 5.4 hrs, AST 2.1 hrs, UP 140K, ON 49K, Rot 80K, 315 gpm @ 2800 psi, 5/15K WOB, 120 RPM, Torq on bUm 8 k I off 8.5 k ,Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.5 ppg, Max gas 306 units. Drill 6-3/4" Lateral 'D' Section f/1 0,432' to 11619' MD, 3550' TVO (1187'), ART 6.9 hrs, AST 1.3 hrs, UP 157K, DN 53K, Rot 90K, 315 gpm @2950 psi, 2/10K WOB, 120 RPM, Torq on bUm 10 k I off bUm 10 k ,Arrived clean hole ECD's from PWD 11.3 ppg, Ave ECD's 11.6 ppg, Max gas 286 units. Drill 6-3/4" Lateral 'D' Section f/11 ,619' to 11,833' MD, 3539' TVD (214'), ART 1.5 hrs, AST 0.4 hrs, UP 170K, DN 50K, Rot 95K, 315 gpm @ 3500 psi, 2/14K WOB, 120 RPM, Torq on bUm 10K I off bUm 10K, Ave ECD's 12.0 ppg, Max gas 393 units, Pump weighted Hi-vis sweep Printed: 11/12/2004 11:23:10AM Legal Well Name: 1E-114 Common Well Name: 1E-114 Spud Date: 9/25/2004 Event Name: ROT - DRILLING Start: 9/25/2004 End: 10/26/2004 Contractor Name: n1334@ppco.com Rig Release: 10/26/2004 Group: Rig Name: Doyon 141 Rig Number: Hours Code Sub Code 1 0/21/2004 00:00 - 03:00 3.00 DRILL DRLH PROD3 on last connection. 03:00 - 04:15 1.25 DRILL CIRC PROD3 Finish pumping out Hi-vis sweep (Increase in cuttings 20%). 04: 15 - 04:30 0.25 DRILL OBSV PROD3 Survey, Record slow pump rates, Monitor well. 04:30 - 10:30 6.00 DRILL TRIP PROD3 Back Ream out of hole at drilling rate to 7,725', Pulling speed 45 to 55 ftImin., Pull thru window with no problems. 10:30 - 12:00 1.50 DRILL CIRC PROD3 Pump weighted Hi-vis sweep, Circ hole clean at 315 gpm @ 2350 psi. 12:00 - 15:00 3.00 DRILL TRIP PROD3 RIH fl 7,725' to 11,800', Wash f/ 11,800' to 11,833'. 15:00 - 17:00 2.00 DRILL CIRC PROD3 Circ at rate of 315 gpm @ 3400 psi, Change over to Solids free MOBM. 17:00 - 20:30 3.50 DRILL TRIP PROD3 Monitor well, POOH on elevators to 7,725', No problems 20:30 - 20:45 0.25 DRILL OBSV PROD3 Monitor well- OK. 20:45 - 00:00 3.25 DRILL TRIP PROD3 POOH to BHA @ 251 '. 10/22/2004 00:00 - 02:00 2.00 DRILL PULD PROD3 Lay down 2 jts. HWDP & Jars, 1 stand NMDC's., Down load MWD tools, Lay down MWD tools, Motor & Bit. 02:00 - 03:00 1.00 WINDO CMPL T3 Make up Baker whipstock retrieving tools, RIH wI 4-3/4" DC's. 03:00 - 06:00 3.00 WINDO CMPL T3 RIH to 7,403', Record UP 137K, DN 80K, Break circ. 06:00 - 06:30 0.50 WINDO CMPL T3 Hook whipstock on 2nd attempt on depth @ 7,471', Pull 60K over and unseat trip anchor, Pull up to 7,403'. 06:30 - 07:30 1.00 WINDO CMPL T3 Circ btm's up at rate of 8 bpm @ 2750 psi. 07:30 - 13:00 5.50 WINDO CMPL T3 POOH to BHA. 13:00 - 15:00 2.00 WINDO CMPL T3 Lay down whipstock retrieving tools, whipstock and space out pipe. 15:00 - 16:00 1.00 CASE CMPL T3 Clean rig floor, Rig to run 4-1/2" Slotted liner. 16:00 -19:30 3.50 CASE CMPL T3 Run 3-1/2" Shoe & Bent joint, XIO's, Total of 61 joints Blank (1,891.52') and every other joint Slotted with total of 59 joints (2,387.58'), Last 2 joints Blank, Ran total of 120 joints, Ran total of 118 6-1/2" x 4-1/2" Spiralgliders 1 per joint for 118 joints. 19:30-21:30 2.00 CASE RUNL CMPL T3 Make up Baker Model B1 Flanged Hook Hanger, RIH w. liner to top of window @ 7,465'. 21 :30 - 21 :45 0.25 CASE RUNL CMPL T3 Break eire, Record UP wt of 97K, DN 60K, Torque at 10 RPM 3500 fVlb, Attempt to rotate at 10 RPM while lowering down past window, RIH & tag down on lower liner at 7,764' (On depth), Pick back up to 10' above window, Rotate 4 rounds and release torque, RIH and enter window on 2nd try. 21 :45 - 00:00 2.25 CASE RUNL CMPL T3 Continue RIH wI liner to 11,160' with no problems. 10/23/2004 00:00 - 00:30 0.50 CASE RUNL CMPL T3 Continue RIH with 4-1/2" liner to 11,808'. 00:30 - 01 :00 0.50 CASE RUNL CMPL T3 Ran past bottom of window @ 7,477' to 7,487'- 6 times turning Hook 3/4 turn each time until Hooked wI 35K (Found bottom of window 2.26' low), Top of liner @ 7,462.43', Shoe @ 11,808.89', Rehook wi 35K, Unhook - turn 1/2 turn and run past window 10', Turn 3/4 turn 2 more times and rehook w/35K to confirm at same depth. 01 :00 - 01 :30 0.50 CASE CIRC CMPLT3 Drop ball, Pump down at 3 bpm @ 600 psi, Pressure up to 3200 psi & Release from hanger. 01:30-02:15 0.75 CASE CIRC CMPLT3 Circ btm's up at 8 bprn @ 2700 psi. 02:15-06:30 4.25 CASE OTHR CMPLT3 POOH, Lay down liner running tool. 06:30 - 08:15 1.75 CMPL TN RUNT CMPLT3 PJSM, Rig & Ran LEM assembly as per detail. 08:15 -13:00 4.75 CMPL TN RUNT CMPL T3 RIH wI LEM on drill pipe to 7,477' (Unable to work past 7,477'). 13:00 - 14:30 1.50 CMPL TN RUNT CMPLT3 Attempt to work thru hook hanger @ 7,477' - Tried all combinations of orientaions and slow rotation. Mule shoe would not penitrate hook hanger port to main well bore. 14:30 - 18:30 4.00 CMPL TN PULL CMPLT3 POOH to LEM Assembly. 18:30 - 20:30 2.00 CMPL TN PULL CMPLT3 Rig, POOH & Lay down LEM assembly, Lay down swivel,Stand back tubing in derrick, Lay down Seal Aseembly. 20:30 - 22:00 1.50 CMPL TN RUNT CMPLT3 Make up new Seal Assembly on bent joint, Run tubing from derrick, Make up LEM Assembly. Printed: 11/12/2004 11:23:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Date Sub Code Code Phase 2.00 CMPL TN RUNT CMPL T3 1.50 CMPL TN TRIP CMPL n 4.50 CMPL TN TRIP CMPL T3 From - To Hours 10/23/2004 10/24/2004 22:00 - 00:00 00:00 - 01 :30 01 :30 - 06:00 06:00 - 09:15 09:15 -11 :30 3.25 CMPL TN TRIP CMPL n 2.25 CMPL TN PULD CMPL T3 11 :30 - 12:00 0.50 CMPL TN PULD CMPL T3 12:00 - 15:30 3.50 CMPL TN TRIP CMPLn 15:30 -16:00 0.50 CMPL TN TRIP CMPLT3 16:00 - 16:45 0.75 CMPLTN CIRC CMPLT3 16:45 - 20:00 3.25 CMPL TN TRIP CMPLT3 20:00 - 21 :00 1.00 CMPL TN PULD CMPLT3 21 :00 - 23:30 2.50 CMPL TN PULD CMPL T3 23:30 - 00:00 0.50 FISH FISH CMPL n 10/25/2004 00:00 - 01 :00 1.00 FISH FISH CMPL T3 01 :00 - 02:30 1.50 FISH FISH CMPL n 02:30 - 06:15 3.75 FISH FISH CMPL n 06:15 - 06:45 0.50 FISH PULD CMPL T3 06:45 - 12:00 5.25 FISH TRIP CMPL T3 12:00 - 13:00 1.00 FISH TRIP CMPL T3 13:00 - 13:30 0.50 FISH TRIP CMPL n 13:30 - 14:00 0.50 FISH TRIP CMPLT3 14:00 - 14:30 0.50 CMPL TN PCKR CMPL T3 14:30 - 15:00 15:00 - 19:30 0.50 CMPL TN DEOT CMPL T3 4.50 CMPL TN PULD CMPL n Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: RIH wI LEM Assembly on drill pipe to 4,750'. Cont TIH to 7468' Work Tight spot @ 7468' - Up wt 135k, Dn wt 85k - Worked past to 7513' stopped - Unable to work past 7513' - Tried several orientation multiple times wI up to 30k dn wt max. No results. After a conference with the town engineers workes several orientataions and set 50 k down wt on string. NO results. Could not get past 7513' TOH RIU & UD LEM assy - Clean rig floor of tools - Confer with engineers in town. Decision was made to attempt to run the LEM only to see if it would clear and Latch in. P/U bent jt wI seal assyon bUm and LEM only - XO to DP TIH to 7733' -( Top of "B" lat. ZXP @ 7732') Did not see ANY obstructions of any kind) It appears the Liner and Hook hanoer are out the window - Up wt 138k, Dn wt 85k TOH to 7410' to be above window. CBU - Monitor well - Static- MOBM 9.3 ppg, Vis 86 out & in, PP 1200, PR 60 spm, 255 gpm - Small show of oil on BU - Gas<50 units. TOH UD LEM and clear & clean rig floor - Discuss options with town - The decision was made to attempt to fish the Hook Hanoer& liner and attempt to re-hook hanger. MU Baker liner running tool wI bent jt of 2 7/8" under tool with circu sub and bull nose. TIH to 7450' MU top drive and attempt to orient out window. Orient bent joint thru window- Work torque in 1/2 turn per attempt - Total of 9 attempts and ran retreiving tool out window. Latched up running tool @ 7503' (Top of hook would be @ 7488'). PU Hook and Liner and work back thru window - No over pull, Liner free. Up wt 156K, Dn wt 65k. Orient and set hook hanger wI 30k dn, repeat release and hook 3 times to assure proper hook. Final hook all at same depth mark on DP w/35k dn wt.. Top of liner 7463.17' Drop 29/32" ball and pump down - Last 5 bbls slow to PR 1.5 BPM, PP 300- Ball on seat - Pressure up to 3400 psi to release tool.- PU - tool free Monitor well - Static - TOH Make all service breaks and UD Baker running tool. Clear all tools from rig floor - RIU & PIU LEM assy per well plan. Seals will be run on bent jt. 10" bent, 14' up from seals.- TIH Con't TIH to 7460' Orient bent jt thru Hook Hanger @ 7472' into main well bore. Con't TIH to TOP of ZXP - @ 7758' seals became tight w/25k dn wt - Work seals down to 7763' and latch LEM at proper depth. Pull test LEM to 10k "OK" Drop 29/32" ball and pump down - PR 3 BPM, PP 675. Slow to 1.5 bpm last 5 bbls - Ball on seat - Pressure up to 2900 psi to set packer, wait 5 min - Con't to pressure up to 3500 psi to neutralize tool. When tool neutralize it showed release.-P/U 2' free. Close annular and test packerto 1000 psi fl10 min "OK" TOH - UD HWDP & DCs - UD Hybred SWDCs Printed: 11/12/2004 11 :23:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-114 1 E-114 ROT - DRILLING n1334@ppco.com Doyon 141 Date Sub Code Code Phase From - To Hours Start: Rig Release: Rig Number: 9/25/2004 10/26/2004 Spud Date: 9/25/2004 End: 10/26/2004 Group: 4.50 CMPL TN PULD CMPL T3 "'Note'" MUD DOG not cleaning MOBM out of inside of DP. We will stand back DP in derrick and let it drain. ( Will have 111 stds 4" DP in derrick - All else has been laid down. All HWDP, Hybred stands and DCs) TOH standing back 4" DP in derrick Make service breaks and UD running tool. 10/25/2004 15:00 - 19:30 19:30 - 21 :30 2.00 CMPL TN TRIP CMPLT3 21 :30 - 22:30 1.00 CMPL TN PULD CMPL T3 22:30 - 23:00 0.50 CMPL TN RURD CMPL T3 23:00 - 00:00 1.00 CMPL TN PULD CMPL T3 10/26/2004 00:00 - 00:15 0.25 CMPL TN SFTY CMPL T3 00:15 - 07:00 6.75 CMPL TN RUNT CMPL T3 07:00 - 09:45 2.75 CMPL TN RUNT CMPL T3 09:45 - 10:15 0.50 WELCTL OTHR CMPL T3 10: 15 - 13:00 2.75 WELCTL NUND CMPLT3 13:00 - 15:00 2.00 WELCTL NUND CMPL T3 15:00 - 16:00 1.00 CMPL TN RURD CMPL T3 16:00 - 18:00 2.00 CMPL TN PULD CMPL T3 18:00 - 19:00 1.00 WELCTL EQRP CMPL T3 19:00 - 23:30 4.50 CMPL TN PULD CMPL T3 23:30 - 00:00 0.50 CMPL TN OTHR CMPL T3 R/U and pull wear bushing Remove all un-needed tools, subs, ecl. from rig floor - Clean working area of MOBM - R/U 4 1/2" tbg running tools and power tongs. Held PJSM on running 4 1/2" completion Ran 4 1/2" 12.6#, L-80 IBTM tbg with completion assembly to 7,400', ran a total of 235 jts 41/2" tbg Spaced out completion string, MU tbg hanger and landed tbg at 7,446' RILDS, landed tbg with open CMU sliding sleeve at 7,370' and DB-6 nipple at 522', st wt up 90K, down wt 57K, block wt 34K , tested hanger seals to 5,000 psi for 10 min, installed TWC Flushed out BOP stack ND BOP stack and set off NU Vetco Gray adapter spool and tree, tested void and tree to 5,000 psi for 10 min, pulled TWC RU to freeze protect well, clear cellar area and RU scaffolding Began LD 4" DP from derrick, freeze protected well while LD DP, displaced out 9.3 ppg OBM with diesel thru open CMU sliding sleeve at 7,370', displaced hole with 300 bbls of diesel at 6 bpm at 900 psi Installed BPV using lubricator Fin LD 4" Dp from derrick, LD a total of 112 stds Cleared rig floor and secured well RELEASED RIG @ 24:00 hrs 10/26/04, rig to move to 1E-168 Printed: 11/12/2004 11:23:10AM Conoc~illips ConocoPhillips Alas!nco,Slot #114 Pad 1E, Kuparuk River Unit,North Slope, Alaska wellb.114 Wellpath: GSS<0-174'>MWD w/Sag-IIFR<305 - 11857'> Date Printed: 8-Nov-2004 "iI. BAKER HUGHES INTEQ I~'bore 114 I creat~ 27 -Se 2004 I Last Revised 25-0ct-2004 IWell ~ Slot Name InstallatiOn Pad 1E I ~-~~~~~~~I~OO I L5~~~_~~~:d 550528.194 5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datum True I =~k R;~, Uo' ,CreatedB Comments I EaStin~ 87754 6208 I~=~ tøVJ- I R ERICAN DATUM 1927 datum ' True INorth~ 48985 8206 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7272.33 Feet on azimuth 47.97 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Äót{-/7( y ConocoPhillips ConocoPhillips Alas~c.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellb.114 Wellpath: GSS<O-174'>MWD w/Sag-IIFR<305 - 11857'> Date Printed: 8-Nov-2004 r&i. BAKER HUGHES INTEQ WellDath (Grid) ReDort MD[ft] 'nc[deg] Azi[deg] TVD[ft] Station Station Dogleg 5everit) Vertical Easting Northing Position(Y) Position(X) Sectionrftl 000 o on 0.00 0.00 O,OON O,OOE 000 0,00 <;<;0'101 00 <;O<;OAA 1 (\(\ 10R 00 000 o no 10R 00 O.OON O.OOE 0.00 0.00 550301.00 <;O<;OAA 1 (\(\ 174.00 0.25 340.00 174.00 0.14N 0.05W 0.38 0.13 550300.95 5959681.13 '10<; ()4 1 17 74 Q'I 305.03 O,75N U5E 0,93 0.80 <;<;0'102 14 <;O<;OAA1 7A 1<;<; 00 2 RO RR 00 '1&;4 QR 0.96N 2.77E 2.94 1.07 <;Ot:;OAA 1 OA 397.01 4.25 90.32 396.90 1.02N 5.28E 3.97 1.23 550306.27 5959682.06 4RR no QR<; Q'I4Q 487.18 O.54N 16.27E 5.95 1.19 :J:JUJ .LD <;Q5QRR 1 R5 57R 1R 12.R'I QR'IR <;75RR 1.36S 33.57E 3.46 -0.02 <;<;(\':I"td.<;7 5959679.R7 671.33 13.82 95.88 666.34 3.98S 54.71E 1.42 -1.79 550355.73 5959677.38 7M.OR 17.R2 Q7.RR 755.58 6.99S 79.65E 4.13 -3.80 5959674,&;4 R55R6 ?3.1R 9907 R41 .5Q 11 RQ~ 111 29E 6.08 -.7.24. 550412.35 t:;Q<;QR7o.nt:; 947.81 26.13 99.57 925.15 17.915 149.13E 3.22 -11.94 550450.23 5959664.09 1041 R1 2R 1Q Q97R 100R.RO 25.11S 191.34E 2.20 -17.44 550492.48 5959657.1 R 1133BO 3456 99.59 1 OR7 .27 'I11R~ 23R R'IF 6.91 -.23.60. """"<100" 44 1226.93 39.96 101.28 1161.37 43.425 294.05E 5.90 -31.64 550595.30 5959639.55 1120 12 4471 101 RR 12'10 24 <;<; Q2~ 355.53E 5.11 -41.67 "7 141137 4756 10146 1293 4R R9 11~ 419 QRF '111 -5227 550721,39 rnrnD. ,71 1504.24 52.06 101.61 1353.38 83.29S 489.47E 4.85 -63.67 550790.97 5959600.99 15971R 5R M 1001R 140R 1 Q Q7 7n~ 564.51E 7.19 -.75.06 168873 6531 99,05 14491R 111168 R4415F 7 '17 -85,34 rnrnr"7 A 1 A 1783.62 71.37 98.50 1484.19 124.605 731.26E 6.41 -95.28 551033.01 5959561.31 1R7q Qq R740 Q72<; 1 <;1 R 12 nR Q7~ 820.59E 4.29 -.104.07 A. 1 Q7? 00 67,14 q8.95 15&;4 02 14q04~ q054'1E 171 -112,75 2067.75 68.46 97.21 1589.86 161.385 992.37E 2.20 -121.60 551294.33 5959526.28 215q.17 RROQ qR.RR 1R22.QR 173.165 1076.77E 1.65 -130.00 5513787q 2252.19 71.83 9q,01 1654.07 1R6.645 1163.1RE 2.Q6 -140.01 rr. ocr AO 2345.02 72.50 98.95 1682.50 200.435 1250.66E 0.72 -150.30 551552.85 5959488.96 2437.R7 71.44 QR.R2 1711.24 214.07S 1337.89E 1.15 -160.44 55164.0..16 5959475.91 2529.88 71.41 99.52 1740.55 227.975 1421.QQE 0.72 -170.89 2623.05 72.73 98.67 1769.23 241.98S 1511.52E 1.66 -181.39 551813.96 5959449.17 2714R7 72 OR QQ22 17Q7 on 2<;55Q~ 1 <;07 OAI: 0.93 -1il1.53. An :1" 2ROQ 40 69.37 97.72 1 R2822 2RR,745 1 ARA ??I: 3?2 -201.15 2901.79 70.34 99.26 1860.04 281.55S 1772.00E 1.88 -210.52 552074.67 5959411.35 ?OQ4 7"- 707Q 9Q,54 1RQOQ7 2Q5B6S 1A<;A .1171: 05R -22137 <;t:;?1I';1 ?'I 'IOR7 Q4 71 RI'; 99.63 1920.81 ~." rDC' 10"" "<It: 1.15 -232.58 3180.26 72.12 99.86 1949.35 325.42S 2032.06E 0.37 -243.97 552334.99 5959369.22 'I?72 77 7? t:;o 99.53 197746 340.275 211894E 0,51 -255.33 t:;<;?421 QR ~^~^~~ ^^ 'I'IRR n2 714'1 QR <;2 200R'I'I 354.18S 2?OR <;1F 1.54 -265.73 """0<1" 1 <::" 3459.29 71.57 98.44 2035.93 367.225 2293.99E 0.17 -275.27 552597.17 5959329.18 '1<;512'1 RRRQ 97.80 2067.02 379.44S 2379.64E 2.99 -284.06 5959117,51 1M2.74 M. R4 QR.RR 2102 Q7 391.49S 2462.90E 4.51 -292.77 55276622 3736.45 71.08 99.91 2138.12 405.54S 2548.57E 6.77 -303.38 552851.98 5959292.57 'IR2R.0<; 7'17<; QR.Q<; 2165.79 419.83S 2634.71E 3.08 -314.22 1Q1474 7072 QQ.42 21'12.24 433.01S 2716.19E 3.53 -324.13 553019J6 4014.73 68.27 100.41 2227.26 449.13S 2808.44E 2.62 -336.55 553112.11 5959250.73 4107 7R R7.QQ 99.99 2261.93 464.42S 2893.43E 0.52 -348.43 553197.19 1 413714 R7<;0 QQ72 227'1 04 4RQ07~ ?O?(\ ?(\I: 1.87 -15201 <;Qt:;Q2'11 <;'1 4279.57 66.50 101.96 2328.70 493.71S 3048.96E 1.61 -371.49 553352.89 5959207.75 4'174 R2 7n 1 <; 100 '11 2'1R'I RO <;10 7<;~ '11'1<; R1F 4.17 -385.05 "0"0101 ':I" 446791 701Q 9Q59 ?'IQ5 4R <;2<;Q2S ':I??? (\71: 07'1 -196 75 4561.31 70.19 98.08 2427.11 539.41S 3308.88E 1.52 -406.77 553613.08 5959163.80 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.ooN O.OOE on azimuth 2.29 degrees Bottom hole distance is 7272.33 Feet on azimuth 47.97 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · c:onoarPt,illips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1E, Kuparuk River Unit,North Slope, Alaska wellb.114 Wellpath: GSS<0-174'>MWD w/Sag-IIFR<305 - 11857'> Date Printed: 8-Nov-2004 ,&¡. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ftJ Inc[degJ Azi[degJ TVD[ftJ Station Station Dogleg Severit} Vertical Easting Northing Position(Y) Position (X) Sectionlftl 4R!'i~ ~R 70 ~1 9R M ?4!'iR ?? !'i!'i0 74~ ':I':IOA 7R¡:: 117 -414 R!'i ".""."."." "". 474724 R9R1 9R70 ?490~R !'iR1?1~ ':IllR? ':ILI¡:: 07R -421,62 ".""'"..,, 17 4841.26 69.57 96.33 2523.17 571.218 3569.89E 0.37 -428.11 553874.28 5959133.76 49~ 41 R9R9 9!'i !'i0 ?!'i!'i!'i !'i9 !'iRO ?1~ ':11::<;1:: 711¡:: o R!'i -4~~6~ !'i!'i~961,18 ".""."."". ':IA 5028,~ 6983 9574 ?588 09 58R84~ ':I7111111<;¡:: 028 -438,75 5121.51 69.92 95.04 2620.15 597.058 3831.55E 0.71 -443.48 554136.08 5959109.66 5?1554 R95R 94 OR ?R!'i? 71 R04 O!'i~ 10!'i -44R9R ".""."."" ')¡:: 5308.75 69.49 M59 2R85.31 610.R4S .,,"~ ".".~ 0.54 -450.06 554311.15 5390.01 69.37 95.76 2713.86 617.50S 4082.32E 1.36 -453.89 554386.95 5959090.90 5485.87 69.48 M.75 2747.55 625.72S 4171.69E 099 -458.53 554476.37 "''''''''''0'' "0 5579.18 68.34 9024 2781.15 629.525 4258.63E 4.67 -458.85 5675.13 68.75 83.41 2816.28 624.57S 4347.73E 6.84 -450.35 554652.38 5959085.61 5768.79 69.47 74.65 2849.73 607.925 4433.52E 877 -430.29 !'i9!'i910? R~ !'iRR? ?R RR?~ 72.54 2884.98 583.495 4516.58E 4 n!'i -40? .!'iR 595912781 5955.62 64.94 69.99 2923.56 556.218 4597.06E 2.85 -372.07 554901.22 5959155.63 6050.51 64.79 68,08 296387 525,475 4hll,LIt-. 1.83 -338.16 !'i549R1 ?? R14? ?R R4 91 RR07 ~no? R7 493.125 A7<;':I71::¡:: 199 -~O? 7R "''''''''''''7 AO 6236.58 64.16 60.59 3043.45 454.93S 4829.82E 5.31 -261.58 555133.28 5959258.45 6330.91 64.37 55.10 3084.43 409.735 4901.72E 5.25 _?1~ 54 "'''''''''''A 07 "'''''''''''''' 1':1 R4n RO R4 4~ 4R 7R ~1?4 RO ~!'iR 1?~ RU -1!'i9 ~ ~~~"~,, ." 6516.59 64.40 44.23 3164.69 300.54S 5028.32E 4.42 -99.38 555330.72 5959414.16 RR10 1~ 64.38 38.76 3205.15 237,395 <;"RA ., R¡:: 5.27 _~4 O!'i <;<;<;':IRI:: 1<; R704 1R R4~ ~4n ~?4!'i RR 1R9 ?1~ "'. ". ",,,r:: 444 ~R 09 6797.34 64.21 29.51 3286.32 97.92S 5178.77E 4.47 109.08 555479.79 5959617.75 RR90 R~ RR n7 24.93 3325.55 22.675 5217.45E 4.88 1R!'i.R? 6984 4? R9 ?9 ?~4R ~~R 1 17 !'iR.4RN ~.7~ ?6631 7 5959772.62 7084.36 72.31 17.21 3394.06 144.91 N 5285.72E 6.63 356.00 555585.11 5959861.28 7177 R7 749n 11.00 3420.47 231.87N 6.95 44~ 7R <;<;<;1::/'\1:: ':ILl 7?71 54 7!'i 17 4.~!'i ~44.R9 ~?1 49N R.RR !'i3380 !'i!'i!'i61781 7363.42 76.69 357.86 3467.05 410.55N 5321.31E 7.05 622.84 555618.92 5960127.11 74!'iR ~~ 77 !'i1 <\!'iR49 348824 503.01 N 1 nR 71!'i 1? <;<;<;1::1 <; ':1<; 7!'i!'i?01 77 ~R ~!'iR R? ~!'iOR R 1 !'iM 4?N o ?1 806 36 ".".".".,,, ." 7645.14 77.57 359.40 3528.83 685.32N 5314.49E 0.85 897.12 555610.26 5960401.80 77~8 M 77R9 ~!'i971 ~54R 9? 77R 9~N o ~!'i 9RR R4 7832,14 79,23 042 3!'i67!'i7 R6R?!'iN 181 1079,88 "'''''''''''0.'' "'''''''''''0, 7., 7925.49 79.71 0.89 3584.63 960.02N 5314.93E 0.71 1171.62 555608.86 5960676.48 801920 R002 1n3 ~R011? 084 126385 <;<;"R1/'\ ?7 8112.37 79.90 1.65 3617.36 0.13 1~!'i!'i !'i9 <;<;<;I::.,? ,)R ." 8206.37 80.26 1.95 3633.55 1236.50N 5322.49E 0.50 1448.18 555614.57 5960952.97 8299.86 80.11 2,47 3R49,49 0.57 1540.30 !'i!'i!'iR17 ')1 R~90 R!'i 80.17 3.03 3665.07 1418.09N 0.61 1 R?9 9!'i <;<;<;1::?1 ?1 5~11~60 8486.34 79.65 3.79 3681.80 1511.94N 5335.94E 0.95 1723.94 555626.17 5961228.47 8580.12 79.92 3.43 3698.43 1604.05N 5341.75E 0.47 1816.21 <;<;<;1::':11 ':II:: RR7~ 10 7971 3.51 3714.87 1695.40N 5347.29E o ?4 190771 <;<;<;I::':II::?O 596141198 8790.65 82.97 3.28 3732.57 1811.39N 5354.17E 2.78 2023.88 555642.39 5961528.00 888427 85.21 1.55 3742.21 1904.42N 3.02 2116.99 <;<;<;&:.iI<;I::O <;01::11::?1/'\<; R977 R1 R!'iR7 ~!'iR4R ~749 R!'i ~ ~~ ??10 1!'i <;<;<;&:.iI<; /'\R "'''~·~·.27 9071.42 87.21 356.53 3755.46 2090.98N 5354.01 E 2.63 2303.24 555640.37 5961807.56 9162.50 90.77 35834 3757.07 2181.94N 4.38 ?~9~ 9R <;<;<;1::':1<; I::R ." 9?!'i7 94 90~ ~!'iR ?R ~7!'iR 14 ??77 ?RN ~".~ ..~ ? ?~ ?4R9 O~ <;<;<;1::':1/'\<;<; 9350.47 90.68 355.45 3755.32 2369.54N 5338.76E 0.95 2580.97 555623.25 5962085.99 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7272.33 Feet on azimuth 47.97 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated y ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellb.114 Wellpath: GSS<0-174'>MWD w/Sag-IIFR<305 - 11857'> Date Printed: 8-Nov-2004 r&ii. BAKER HUGHES INTEQ Well MD[ftJ Easting Northing 555628.76 5962646.83 555631.98 .74 5962927.67 555652.87 555666.73 5964042.70 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7272.33 Feet on azimuth 47.97 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated y ConocoPhillips ConocoPhillips Alas~nc.,Slot #114 Pad 1 E, Kuparuk River Unit,North Slope, Alaska well. 114 Well path: GSS<0-174'>MWD w/Sag-IIFR<305 - 11857'> Date Printed: 8-Nov-2004 r&¡¡. BAKER HUGHES INTEQ Hole Sections Diameter Start Start Start Start End End End Start Wellbore 7 3725.90 1762.27N 11857.00 3788.25 Casin s Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #14195.00 above mean sea level) Vertical Se<:;tion is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distanl;e is 7272.33 Feet on azimuth 47.97 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Re: USIT evaluation lE-114 e . Subject: Re: USIT evaluation lE-114 From: Thomas Maunder <torn _ maunder@adrnin.state.ak.us> Date: Thu, 07 Oct 200410:59:17 -0800 To: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> CC: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com>, "McKeever, Steve" <Steve.McKeever@conocophillips.com>, "Thomas, Randy L" <Randy.L. Thomas@conocophillips.com> Mike, et al: I confirm the discussion this morning between you, Doug Hupp, Mike Martin and myself with regard to the subject log in lE-114. Mechanically it was not possible to reciprocate the casing throughout the cementing operation. From what Steve said yesterday, the casing was moved until the spacer rounded the shoe. No other problems were reported. We examined and discussed the log presentation via phone. I concur with Mr. Hupp's assessment of the "bondedness". Based on the assessment ofthe cement, I also concur that it unlikely that any attempt to do remedial work would have much chance for success. In our discussion we also discussed the USIT log from ID-103 and compare that log to lE-114. The "quality" of lE-114 appears to be better than ID-103 which is encouraging since all indications are that ID-I03 has integrity. Based on the log presentation and discussion, it is concluded that there likely is isolation present, however it is prudent to have logs run in the future to further confirm the isolation. Any further logging while the well is being drilled is at CP AI's option. When the well has been putinto serVice, CP AI should plan to conduct temperature surveys to confirm that there is no upward flow of water above the West Sak. The logging plan should incorporate warm-back passes to help with the assessment. Such log should be planned within 60 days of placing the well in service. Please call or message back with any questions. Torn Maunder, PE AOGCC Greener, Mike R. wrote: The review of theUSIT log for the 1 E-114 by Doug Hupp Mike Greener Senior DriJling Engineer ConocoPhiJJips Alaska, Inc. 907-263-4820 -----Original Message----- From: Hupp, Douglas Sent: Thursday, October 07,20049:52 AM To: Greener, Mike R. Subject: usn evaluation lE-114 Mike Greener As requested by you, below is a description of the USIT cement evaluation log that was run on your lof2 1!l3/2005 6:56 AM Re: USIT evaluation lE-114 e e welllE-114 on 07-0CT-2004. This description is based on the PDS graphics file USI_008LUP, which was e-mailed from the rig to your office. The USIT log presents an interpreted cement map in the right hand track of the print. This is generated applying cutoffs to the raw impedance data, which is presented in 4th track. The cutoff values used as identified in the parameter listing on the print are: Acoustic Impedance of Mud 2.196, Acoustic Impedance Threshold for Cement 2.60, Acoustic Impedance Threshold for Gas 0.3. The red shading indicates gas, blue shading indicates water or mud, green color indicates contaminated or partly set cement, yellow to black color indicates set cement. TD - 8350 Good cement bond with a thin track of contaminated or partly set cement indicated by the green shading. 8350 - 7850 Good cement around 60% to 75% of casing but more contaminated or partly set cement than above (25% to 40% of casing). 7850 - 7835 Good cement. 7835 - 6975 Good cement around 60% to 75% of casing but more contaminated or partly set cement than above (25% to 40% of casing). 6975 - 6880 Good cement around 50% of casing contaminated or partly set cement around 50% of casing, 6880 - 6850 Good cement with a thin track of contaminated or partly set cement. 6850 - 6740 Good cement around 75% of casing but more contaminated or partly set cement around 25% of casing. 6740 - 6730 Good cement. 6730 - 4840 This section grades from good cement around 75% of casing to 25% of casing. Some indications of mud or water appear for up to 10% of the casing. If you have any questions regarding this please call me. Douglas Hupp, PE Schlumberger 263-4529 ConocoPhillips Alaska, Inc. 273-1771 Schlumberger Direct 230-9891 Cell Phone 20f2 lIl3/200S 6:56 AM 1 £-114 cement bond log e . Subject: lE-114 cement bond log From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Thu, 07 Oct 200407:28:45 -0800 To: tom_maunder@admin.state.ak.us K13 marker @ 6,985' Classic bond seal at +/ - 6,750' for your reference. Another at 6,860' to 6,890' and 7,340' to 7,360' All the rest is likely to be Inicro annulus since we were unable to run the log under pressure. I am no log expert on cen1ent bond logs but what I see would be difficult to squeeze if necessary. «USLCE-1.PDS» Mike Greener Senior Drilling Engineer ConocoPhillips Alaska, Inc. 907 -263-4820 Content-Description: us 1_ CE~ 1.PDS Content-Type: application/octet-stream Content-Encoding: base64 I of 1 1/13/20056:52 AM Re: lE-IIA, et aI, again e - Subject: Re: lE-114, et aI, again From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 16 Sep 2004 16:27:04 -0800 To: "Greener, Mike R" <Mike.RGreener@conocophillips.com> CC: "Thomas, Randy L" <Randy.L.Thomas@conocophillips.com>, Steve Shultz <Steven.M.Shultz@conocophillips.com> I hate to keep bothering you all, but on IE-l14 a bond log will need to run. I do not see that a bond log has been included in the procedure. Tom Maunder, PE AOGCC Greener, Mike R wrote: I have printed out the daily reports from DIMS that have the cementing information on them for the wells in question. I will fax these reports to Tom at 11 am today. Mike Greener Senior Drilling Engineer ConocoPhillips Alaska, Inc. 907-263-4820 -----Original Message----- From: Thomas, Randy L Sent: Thursday, September 16, 2004 9:28 AM To: Greener, Mike R. Cc: 't:om maunder@admin. state. ak. us I Subject: FW: 1E-114, et aI, again Steve is out until Monday or Tuesday. This is the application for the next well on the schedule. Can you touch base with Tom to verify what he needs and see if we can pull it together this week to keep the approval process moving? We've got a little bit of time and maybe it can wait until Steve gets back. Let me know what you think. Randy L. Thomas Kuparuk Drilling Team Lead 907-265-6830 office 907-244-5205 cell 907-222-6088 home Randy.L.Thomas@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, September 15, 2004 1:57 PM To: Thomas Maunder Cc: Thomas, Randy L Subject: Re: 1E-114, et aI, again Steve and Randy, I am hitting both of you since I do not know if Steve is in. In addition to the proximity information, I need some information on the wells that offset this well since it is proposed as an injection well. For reference, you can see my column in the AADE newsletter. I I need 7-5/8" cementing information for wells1D-112, 1D-113 and 1D-116. lof2 9/16/20044:27 PM Re: lE-114, et aI, again e e If the completion report for lE-123 has not been submitted, I need the cementing information for that well also. We do not have a whole lot of information in our files on the casing and cementing on these wells. In the summaries, it is essentially one line. Thanks, I look forward to your reply. Tom Maunder, PE AOGCC Thomas Maunder wrote: Hi Steve, I left you a voice message on this. In the lE-114 application, there is nothing regarding close approach or proximity to other wells. Please give me a call. Tom 20f2 9/16/20044:27 PM . (ill . FRANK H. MURKOWSKI, GOVERNOR AItASIiA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 9951 0~0360 Re: Kuparuk lE-114 ConocoPhillips Alaska, Inc. Permit No: 204-171 Surface Location: 5188' FNL, 226' FEL, SEC. 16, TUN, RlOE, UM Bottomhole Location: 319' FNL, 29' FEL, SEC. 15, TUN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (pager). BY ORDER OF THE COMMISSION DATED thisjJ day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation wlo encl. ConoccJt,illipS Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com September 8, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1E~114, 1E-114 L1 and 1E-114 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "A", "B" and "D" sands. The main bore of the well will be designated 1E-114, and the lateral bore of the well will be designated 1E-114L1 ("B" Sand) and 1E-114L2 CD" Sand) Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-114 is 10/1/2004. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, \<-~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECE'VED SEP - 9 2004 CommIssion ~\as\(a Oi\ & Gas Cons. þ.ncnorage ORIGINAL . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL . A/ICr 20 AAC 25.005 1 a. Type of Work: Drill ~ Redrill U Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1b. Current Well Class: Stratigraphic Test 0 ExploratoryU Development Oil U Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 Uë-tt<4 6. Proposed Depth: 12. Field/Pool(s): ./ ,/ MD: 11870' TVD: 3808' Kuparuk River Field / Surface: 5188' FNL, 226' FEL, Sec. 16, T11N, R10E, UM P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): 7. Property Designation: ALK 25651 ' 8. Land Use Permit: 3403' FNL, 176' FEL, Sec. 15, T11N, R1OE, UM Total Depth: 319' FNL, 29' FEL, Sec. 15, T11N, R10E, UM .I 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301./ 16. Deviated wells: Kickoff depth: 300./ ft. 18. Casing Program Size ,/ ADL 469 9. Acres in Property: 2560 / / West Sak Pool 13. Approximate Spud Date: 10/1/2004 Top of Productive Horizon: 14. Distance to Nearest Property: 5104' 10. KB Elevation 15. Distance to Nearest 10.75" 7-5/8" Weight 94# 45.5# 29.7# 12.6# ./ y- 5959681 Zone- 4 (Height above GL): 28 feet Well within Pool: 10-112 @ 920', 17. Anticipated Pressure (see 20 AAC 25.035) ,/ / Maximum Hole Angle: 98.6° Max. Downhole Pressure: 1673 psig I Max. Surface Pressure: 1246 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Grade Coupling Length MD TVD MD TVD (including stage data) K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete L-80 BTC 4154' 28' 28' 4182' 2295' 718 sx ASLite, 189 sx DeepCrete L-80 BTCM 8752' 28' 28' 8780' 3733' 508 sx DeepCrete L-80 DWC 3090' 8780' 3733' 11870' 3808' slotted liner Hole Driven 13.5" 9-7/8" 6.75" Casing 20" 4.5" 19 Total Depth MD (It): PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): EHective Depth TVD (It): Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Size Cement Volume MD TVD Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 Property Plat 0 BOP SketchO Diverter Sketch 0 Drilling programL;J Seabed Report 0 Time v. Depth Plot [J Drilling Fluid Program 0 Date: Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature \ r Randy Thomas .~ , I Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone ~)6-B~ð Date ., I? 10'1 ð-enafRrt hv Sharon AI/sun-Drake Commission Use Only Permit to Drill , I API Number: Permit Approval Number: 204-/71 50-oZ:1-;l.322..3-'cJô Date: ?Þ-//¿:;_0_ Conditions of approval: Samples required 0 Yes ~NO Mud log required' 0 Yes "1fi!: No ~her ';~ \' >;, <:~ F~ ~;::\:'\':; \ ~~ Yes ~~o\' ~:~":~::~'~ $~EJ"ËD . j~V ~ '1'-'?~ ~\ C>.."-:. ~ \Q..~~C.d . SEP 49 2004 /' J ~ ~J BYORDERO"'askaOil&GasC_L / a'V' Approved tJ . ? V\ COMMISSIONER THE COMMISSION Da~: " ,£,1 I II I Form 1~R;::d3l2003.- 0 RIG IN.Ä L /~ubmi~ndu~hcate See cover letter for other requirements · .Iication for Permit to Drill, Well 1 E-114 Revision No.O September 2, 2004 Permit It - West Sak Well #1E-114 ("A" Sand) Application for Permit to Drill Document Moxir'rlizE Well VQIU~ Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................2 2. Location Su m mary....................................................................................................... 2 Requirements of 20 AA C 25.005(e)(2) ..... ...... ....... ..... ........ ....... ............ ....... ..... ....... ...... .... .......... ....... 2 Requirements of 20 AA C 25.050(b) .... .... ....... ....... ............ ........ ............. ..... ............ ....... ...... ..... .., ....... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25. 005(e)(3) ................................................................................................ 3 4. Drilli ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (e)(4) ...............................................................................................3 5. Procedure for Conducting Formation Integrity Tests.............................................3 Requirements of 20 AAC 25.005 (e)(5) ...... ........ ..... .... .... ....... ............ ....... ...... ..... ........ .... .............. ..... 3 6. Casi ng and Ceme nti ng Prog ram................................................................................ 4 Requirements of 20 AAC 25.005(e)(6) ........... ....... ............. ....... ..... ....... ....... ..... ............. ...... ..... .......... 4 7. Diverter System Information ......................................................................................4 Requirements of 20 AAC 25.005(e)(7) .. ..... ........ ....... ....... ..... ...... ....... ..... ......... ............ .... .............. ..... 4 8. Drilli ng Flu id Program................................................................................................. 5 Requirements of 20 AAC 25.005(e)(8) ................... ....... ..... ........ ............ ........... ...... ...... ....... ..... .......... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................5 9. Abnormally Pressured Formation Information ........................................................ 5 Requirements of 20 AAC 25.005 (e)(9) . ............ ....... ....... ..... ....... ...... ...... ........... ........ ...... ....... ....... ..... 5 1 O. Seismic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (e)(10) ........ ....... ...... ....... ..... ........ ............. ... ........ ...... ............ .......... 5 11. Seabed Condition Analysis ................................. ....................................................... 5 Requirements of 20 AAC 25.005 (e)(11) .... ....... ....... ............. ............ ............ ....... ....... ...... ...... ....... ..... 5 12. Evidence of Bonding ........................................... ........................................................ 6 Requirements of 20 AA C 25.005 (e)(12) '. .............. ....... ..... ........ ..... ....... ...... ....... ...... ...... ..... ....... ........ 6 ORiGiNAL PERMIT IT (Injector) RevO.doc Page 10f8 Printed: September 2, 2004 e e/iCation for Permit to Drill, Well 1 E-114 Revision No.O September 2, 2004 13. Proposed Dri lIing 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. Attach ments.................................................................................................................. 8 Attachment 1 Directional Plan ... ...... ...... ....... ....... ..... ........ ...... ..... ....... ............. ....... ..... ........................ 8 Attachment 2 Drilling Hazards Summary..... ......... ..... .............. ..... ....... ............ .............. ..... ................. 8 Attachment 3 Cementing Data.... ...... ..... ............. ...... ........ ............ ...... ........ ..... ...... ...... ...... ......... ........ 8 Attachment 4 Well Schematic .... ............ ....... ...... ..... ....... ........ ............ ....... ........... ....... ..... ......... ........ 8 1. Well Name Requirements of 20 AAC 25.005 (f) 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 branch~ each branch must similarly be identìtìed 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 lE-114. 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 item~ 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 formatio~ 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 I ASP Zone 4 NAD 27 Coordinates Northings: 5,959,681 Eastings: 550,301 FNL:5188', FEL:226', See 16, T11N/RlOE, UM ¡/ I RKB Elevation I 94.5' AMSL I Pad Elevation L 66.5' AMSL Location at Top of Productive Interval FNL:3403', FEL:176, See 15, T11N/RIOE, UM ./ (VVestSakUA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth/ RKB: 8780' Northings:5,961,503 Eastings: 555,615 Total Vertical Depth/ RKB: 3733' Total Vertical Depth 55: 3611.0' Location at Total Depth I FNL:319', FEL:29', See 15, T11N/RlOE, UM / ASP Zone 4 NAD 27 Coordinates Measured Depth/ RKB: 11870' Northings:5,964,589 Eastings: 555,735 Total Vertical Depth/ RKB: 3808' Total Vertical Depth 55: 3713.0' and (D) other information required by 20 MC 25. 050(b); ORIGINAL PERMIT IT (Injector) RevO.doc Page 2 of 8 Printed: September 2, 2004 · e/iCation for Permit to Drill, Well 1 E-114 Revision No.D September 8, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate4 the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well,· Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ 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 item~ 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 MC 25.035, 20 AAC 25.03~ or 20 MC 25.03~ as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete weIl1E-114. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 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 Item~ except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountere4 criteria used to determine it, and maximum potential surface ,I. pressure based on a methane gradient; þþ <} f'f. (? r The expected reservoir pressures in the West Sak sands in the 1E-114 area vary from~0.44 to~0.47 ./ psi/ft, or 8.6 to 9.0 ppg EMW (equivalent mud weight).tlThese pressures are predicted5ased on actual bottom hole pressure data from the nearby West Sak wells. 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 B sand formation is 1245.66 psi, calculated thusly: MPSP =(3560 ft)(0.47 - 0.11 pSi/ft) = 1245.66 psi ./ (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured stratét lost circulation zone~ and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 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 test~ as required under 20 MC 25. 030(f); The parent wellbore,lE-114, will be completed with 75/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance ORIGINAL PERMIT IT (Injector) RevO.doc Page 3 of 8 Printed: September 8, 2004 · .¡¡cation for Permit to Drill, Well 1 E-114 Revision No.O September 2, 2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25. 030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3, APO for 1E-114: Cement Summa~ Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (Ib/ft) Grade Connection (fl) (fl) 1ft) Cement Proqram 20 Driven 94 K55 Welded 80 28 / 28 108/ 108 Cemented to (Encountered surface with water) 260 cf ArcticCRETE 10 3/4 13 1/2 45.5 L-80 BTC 4154 28 / 28 4182 /2295 Cemented to Surface with 718 sx ASLite Lead, 189 sx OeepCRETE Tail 7 5/8 9 7/8 29.7 L-80 BTCM 8752 28 / 28 8780 / 3733 Cement Top planned @ 5500' MO / 2750' WO. Cemented w/ 508 sx OeeDCRETE 41/2 6 3/4" 12.6 L-80 OWC 3090 8780/3733 11870/3808 Slotted- no slotted "A" Lateral cement (lE-114) 41/2 63/4" 12.6 L-80 OWC 4070 7784/3560 11854/3633 Slotted- no slotted "B" Lateral cement (lE-114L1) 41/2 63/4 12.6 L-80 OWC 4357 7492/3494 11849/3574 Slotted-no slotted "0" Lateral cement (lE-114 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 ofthe diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lE-114. Please see diagrams of the Doyon 141 diverter system on file with the Commission. PERMIT IT (Injector) RevO.doc Page 4 of 8 Printed: September 2, 2004 ORIGINAL e elication for Permit to Drill, Well 1 E-114 Revision No.O September 2, 2004 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 MC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Surface Intermediate Production Density (ppg) 8.6-9.2 9.3 9.3 ;; Funnel 150-300 45-55 30 Viscosity (seconds) Yield Point 30-70 26-30 18-28 (cP) Electric Stability NA NA 650-900 Chlorides (mg/I) <500 <500 40000 pH 8.5-9.0 9.0 NjA API filtrate <6 <6 <4 (cc / 30 min) **HTHP filtrate <10 <10 <10 (cc / 30 min) MBT (Ib / gal) NA NA Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 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 20 MC 25.OJ3(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offShore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Applicatíon is not for an offshore well. ORIGINAL PERMIT IT (Injector) RevO.doc Page 5 of 8 Printed: September 2, 2004 · .Iication for Permit to Drill, Well 1 E-114 Revision No.O September 2, 2004 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c){12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met.: Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. 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 for lE-114 is listed below. 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 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 +/- 4182' MD / 2295'1VD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 103/4",45.5#, L-80, 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 and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. ¡/' 6. PU 9 7/8" bit and drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 7 5/8" casing point at 8780 MD / 3733'1VD. 9. Run 7 5/8", 29.7# L-80, BTCM Mod casing to surface. Pump cement and displace with mud and pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead 7 5/8" packoff and test to 5000 psi. \\:::b\I:..;' þ.. ba~~ \ C) \ '\ ') 11. Flush 10 3/4" x 7 5/8" annulus with water, followed by di~el. ~ ~ ~ \ ~, M~ 12. PU 63/4" Bit and drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of q I float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 't l b 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform ¡Í¡~ ~ formation integrity test to leak off, recording results. \. ð 14. Directionally drill 63/4" hole to TD at +/- 11870' MD / 3808'1VD as per directional plan. / b C;-~~~ 15,..., P.O.. 0" H, back reaming out of lateral. POOH. ?t", L I . \ 16. PU and run 4 1/2" slotted liner. \ ' é) 0 \ - \ ~ \ 17. Land liner, set liner hanger POOH. ~~:'~ining operations are covered under the 1E-114L1 Application for Permit to Drill, and a provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 7784' MD / 3560'1VD, the top of the B sand. 19. Mill 6 3/4" window. POOH. ORIGINAL PERMIT IT (Injector) RevO.doc Page 6 of 8 Printed: September 2, 2004 e elícation for Permit to Drill, Well 1 E-114 Revision No.O September 2, 2004 v/ 20. Pick up drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at 11854' MD / 3633' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 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. PU Lateral Entry Module "LEM", RIH, latch into hook hanger, shea rout and POOH Note: Remaining operations are covered under the 1E-114L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of 7492' MD / 3494' ND, the top of the D sand. 29. Mill 63/4" window. POOH. . v 30. Pick up drilling assembly with LWD and MWD and PWD. RIH. ./ 31. Drill to TO of D sand lateral at 11849' MD /3574' TVD, as per directional plan. 32. POOH, back reaming out of lateral. POOH. 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. PU "Lateral Entry Module", RIH, latch into hook hanger, shear out, POOH 38. POOH and Jay down drill pipe 39. RU and run 4 V2" tubing completion 40. Space out tubing and stab seals into PBR, land tubing, pressure up annulus and shear out GLM, set BPV 41. Nipple down BOPE, nipple up tree and test 42. Pressure up annulus and shearout the lower gas lift mandrel, freeze protect well with diesel by pumping into 4 1/2"" x 7 5/8" annulus, taking returns from tubing (diesel all the way around). Install BPV 43. RDMO Doyon 141 44. Rig up wire line unit. Pull BPV 45. Retrieve RP shear, set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 46. Replace gas lift valves with blank dummy valves. 47. Place well on injection. ORIGINAL PERMIT IT (Injector) RevO.doc Page 7 of 8 Printed: September 2, 2004 · .Iication for Permit to Drill, Well 1 E-114 Revision No.O September 2, 2004 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the wel/./ Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE 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 lE 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. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic ORIGINAL PERMIT IT (Injector) RevO.doc Page 8 of 8 Printed: September 2, 2004 Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 9/2/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 120' MD < Sase of Permafrost at 2,002' MD (1,542' TVD) < Top of Tail at 3,300' MD < 103/4",45.5# casing in 13 1/2" OH TD at 4,182' MD (2,295' TVD) Mark of Schlumberger Schl..pgøp CemCADE Preliminary Job Design 103/4" Surface Casing Preliminary Job Design based on limited Input data, For estimate purposes only. 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 3,300' MD. Lead Slurry Minimum pump time: 250 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 felft x (120') x 1.00 (no excess) = 0.3637 ft3/ft x (2002' -120') x 3.50 (250% excess) = 0.3637 ft3/ft x (3300' - 2002') x 1.35 (35% excess) = 163.7 ft3 + 2395.7 ft3+ 637.3 ft3 = 3196.7ft3/4.45 ft3/sk = Round up to 720 sks 163.7ft3 2395.7 ft3 637.3 ft3 3196.7 ft3 718.4 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 170 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637ft3/ft x (4182' - 3300') x 1.35 (35% excess) = 0.5400 ft31ft x 80' (Shoe Joint) = 433.1 ft3 + 43.2 ft3 = 476.3 ft3/2.52 ft3/sk = Round up to 190 sks 433.1 ft3 43.2 ft3 476.3 ft3 189 sks BHST = 45°F, Estimated BHCT = 63°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 Drop bottom plug 0.0 0.0 5.0 33.3 ASL 7.0 569.2 81.3 114.6 DeepCRETE 5.0 84.8 17.0 131.6 Drop top plug 0.0 0.0 5.0 136.6 Water 5.0 20.0 4.0 140.6 Turn over to rig 0.0 0.0 5.0 145.6 Mud 7.0 359.5 51.4 197.0 Slow & bump plug 3.0 15.0 5.0 202.0 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 20, Ty < 15 Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-21, Ty? 20-25 Centralizers: Recommend 1 per joint across zones of interest to assist in mud removal and cement placement. ORIGINAL Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 9/2/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265~205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 103/4",45.5# casing at 4,182' MD < Top of Tail at 5,500' MD < 75/8",29.7# casing in 9 7/8" OH TD at 8,780' MD (3,733' TVD) Scltl..pgøp CemCADE Preliminary Job Design 7.625" Intermediate Casing Preliminary Job Design based on limited Input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 60% excess. Tail slurry is designed for 425' MD above top of Ugnu sands - (3280' MD annular length). Tail Slurry Minimum thickening time: 200 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.2148 ft3/ft x 3280' x 1.60 (60% excess) = 0.2578 ft3/ft x 80' (Shoe Joint) = 1127.3 ft3 + 20.6 ft3 = 1147.9 ft3/2.26 ft3/sk = Round up to 510 sks 1127.3 ft3 20.6 ft3 1147.9 ft3 507.9 sks BHST = 82°F, Estimated BHCT = 71°F. (BHST calculated using a gradient of 2. 6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Cumulative Stage Time Time (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20,0 MUDPUSH II 6.0 50.0 8.3 28.3 Drop bottom plug 0.0 0.0 5.0 33.3 DeepCRETE 6.0 204.4 34.1 67.4 Drop top plug 0.0 0.0 5.0 72.4 Mud 7.0 384.5 54.9 127.3 Slow & bump plug 3.0 15.0 5.0 132.3 MUD REMOVAL Recommended Mud Properties: 9.2 ppg, Pv < 12, Ty < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 21 - 23, Ty = 25 - 28 Centralizers: 5400 - 5900, 1 bow spring per joint 5900 - 7020, 1 ~ bow spring per joint 7020 - 8700, 1 ~ tandem rise per joint 2 tandem rise on the shoe track ORIGINAL ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot#114 Well: 114 Wellbore: 114 Seale 1 em = 250 ft East (feet) -> 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 -1000 -500 0 500 1000 1500 1E-114/L1/L2TD LOCATIONS: 319' FNL, 29' FEL SEC. 15, T11N, R10E ./ TD,4 1/2 Liner PI. 1E·114TOPWEST I SAK Þ2 LOCATION: 1876' FSL, 176' FEL . SEC 15, T11N, R10E 1E-114 TOP WEST SAK B LOCATION: 896' FSL,217' FEL SEC. 15, T11N, R10E 1E-114 TOP WEST SAK 0 LOCATION: 612' FSL, 229' FEL SEC. 15, T11N, R10E Top West Sak A2, 75/8" Csg. PI. I ESTIMATED SURFACE LOCATION: 91' FSL, 226' FEL I SEC. 16, T11N, R10E End Milled Openhole, KOP Base Whipstock Face Top~iWgs1~f<CS End Mi~d Q~nhrJek~.9~ Bas:flNf\lW.s10c~ F'ãce Top West Sak D f2'1")(j <00'1:> (¡I'}¡þ Ì':, ~r¡, 'G'el")t , S/(j-?; rl) <t .$/700 të;'1(' )-Oþ C~6'/~ <00'1:> Ú.9I")V '{lÞf vI'}¡ C . 'IJ'h ë;'r¡, 'G'el")f r L I L L I L ~ EOC t Curve 31100 L I ~ EOC ~ Bid 4/100 t 7 5/8in Casing I ~ ¡ ï ~ r r I r I r i r ~ L j~14L21 ì I rr A-3 A-4 ~oc Build 3/100 EOC K-13 Top Ugnu A Top Ugnu B ~ L I ¡ 5500 5000 4500 4000 3500 3000 ^ I 2500 Z o ::+ 2000 ,:: ø' CD - 1500 - 1000 500 o (f) (') -500 ~ (') 3 -1000 1\ I\) c.n o -1500 ;::I! Conoc~illips raate anner Date plotted: 9-Au9-2004 at ra erence IS 1 4. Ref well path is 114 Verso #2, Coordinates are in feet reference Slot #114. True Vertical Depths are reference Rig Datum, Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea leYeI: 95.00 ft. Plot North is aligned to TRUE North, . e ~illips . ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 1 Wellbore: 114 Wellpath: 114 Verso #2 Date Printed: 9-Aug-2004 øtA: INTEQ ~"",-_.._--"-~~'_._"--'~'-'------~--"--_._---.---~.-''-'~------'----'~'---'_"-"---------"--~'----'-_"_-'"- - ~----~--'--""'--~-'-"-----------"-"'_'------'.--- - ----.~..~.__.__.-.---.-.,,--..._._--_._-_.._.._~.-~---~~.~--~-"--'-'-------'~--~--~'- ._--~---~---- Wellbore Name ___~__'________~_~__________ .created_~_________~, astK~vised ~~____ J_~________,,___ ~__ ~ ~~_____ j~:-Ai&-2a(M___ ,_______ ~___________ _9:Aua-2004_______~______ --'--~-_.~-- Well Name 114 Slot Name Slot #114 18 2.2151 35 33.3755 Installation Name Pad 1 E ,¡ Field Name Ku aruk River Unit All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.aft above mean sea level) Vertical Section is from a.aaN a.aaE on azimuth 2.29 degrees Bottom hole distance is 7323~a8 Feet on azimuth 48,30. degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL c:onoOOPi,¡Yips ConocoPhillips .tka, Inc. ,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 2 Wellbore: 114 Wellpath: 114 Verso #2 Date Printed: 9-Aug-2004 ..: INTEQ Well path Report MD[ft Inc[deg Azi[deg lVD[ft Vertical North[ft East[ft Station 8tation Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 8ection[f -------- ,.----~-- ~~._-_._. --- ----~~ ~--~ ~--_.- ~ºJ:!!1L_______ I-East\ Oft1 tL___ ------ -- _ 0.00__ -Q.-ºQ-- ___QJJ_O__ --Q,QQ-- _ -95.0Q_ __QQQ1'L. _-º,ºQt;__ l)959Ei(jlºº- _55030.1JJ-º-- -.-O,Qº- _ 0.00_ lie OIL,,______.,__ -._---~""~~_._-,~.~-- 100.00 0.00 0.00 100.00 5.00 O.OON O.OOE 5959681.00 550301.00 0.00 0.00 200.00 -ºJ1!L --º'-º-º--- _20º,-illL _J05.Q_º- _ O.OON _._ JLQQL .2ª-5968"LQQ_ _ 550301.00 0.00 O.illL_ --~---~-_.~~--~~-~- 300.00 0.00 0.00 300.00 205.00 O.OON O.OOE 5959681,00 550301.00 0.00 0.00 KOP End of Hold --- 400.00 3.00 98.57 399.95 304.95 0.398 2.59E 5959680.63 550303.59 3.00 -0.29 500.0Q_ ~Q.. ___ 98.51:_ _4.99 63 __404.6.L _L5_~ -.J0.35E_ 5959679.51 r_Q50311.~~ _~OO _ -1.14_ ------~---_._,--- 600.00 9.00 98.57 ,- 598.77. ~~77 . -~~ 23.25E 5959677.65 550324.27 3.00 -2.57 ..--- 633.33 10.00 98.57 631.64 536.64 __4.328 28.69E 5959676.87 _55032-ª. 72 3.00 -3.17 BldlJrn 4/1QO. End of BuildlTurr] -- 733.33 14.00 98.57 729.44 634.44 7.428 49.25E 5959673.91 550350.29 4.00 -5.45 833.33 18.00 98.57 825.54 730.55 11.538 76.50E 5959669.99 550377.56 4.00 -8.46 - 883.33 20.00 98.57 872.82 777.82 13.958 92.59E 5959667.67 550393.67 4.00 -10.24 BldlTrn 6/100. End of Build 983.33 26.00 98.57 964.83 869.83 19.778 131.21 E 5959662.11 550432.33 6.00 -14.51 1083.33 32.00 98.57 1052.25 957.25 27.00;; 179.13~ 5959655.21 550480.29 6.00 -19.82 1183.33 38.00 98.57 1134.13 1039.13 35.548 ~2.E.. ~-ª-647.04 550537.03 6.00 -26.09 1283.33 44.00 98.57 1209.56 1114.56 45.318 300.66E 5959637.71 550601.93 6.00 -33.26 -- 1383.33 50.00 98.57 1277.73 1182.73 56.208 372.95E 5959627.30 550674.28 6.00 -41. 26 1483.33 56.00 98.57 1337.89 1242.89 68.108 451.89E 5959615.93 550753.29 6.00 -49.99 1583.33 62.00 98.57 1389.37 1294.37 80.87S 536.61E _5959603,73 550838.08 6.00 -59.36 1683.33 68.00 98.57 1431.61 1336.61 94.378 626.18E 5959590.84 550927.74 6.00 -69.27 1713.33 69.80 98.57 1442.41 1347.41 98.54S 653.86E 5959586.85 550955.44 6.00 -72. 33 EOC. End of Build 1800 00 69.80 98.57 1472.33 1377.33 110.668 734.29E 5959575.27 551035.94 0.00 -81.23 1900.00 69.80 98.57 1506.86 1411.86 124.648 827.09E 59595,61.91 551128.82 0.00 -91.49 ?OOO.OO 69.80 98.57 1541.39 1446.39 _138.638 919.89E 5959548.55 551221.71 0.00 -101.76 2001.76 69.80 98.57 1542.00 1447.00 138.878 921.52E 5959548.31 551223.34 0.00 -101.94 Base Permafrost 2100.00 69.80 9857 1575.92 1480.92 152.618 1012.69E 5959535.11L 551314.59 000 -112.03 2200.00 69.80 98.57 1610.45 1515.45 1Q6.60S 1105.49F 5959521.82 551407.47 0.00 -122.29 -- 2300.00 69.80 98.57 1644.98 1549.98 180.588 1198.30E 5959508.46 .....Q51500.36 0.00 -132.56 2400.00 69.80 98.57 1679.51 1584.51 194.57S 1291.10E 5959495.10 551593.24 0.00 -142.82 2500.00 69.80 98.57 1714,04 1619.04 208.558 1383.90E 5959481.73 551686.13 0.00 -153.09 2600.00 69.80 98.57 1748.57 1653.57 222.548 1476.70E 5959468.37 551779.01 0.00 -163.36 -~ 2700.00 69.80 98.57 1783.10 1688.10 236.528 1569.50E 5959455.01 551871.89 0.00 -173.62 2708.39 69.80 98.57 1786.00 1691.00 237. 708 1577.29E 5959453.89 551879.69 0.00 -174.48 Too T-3 2800.00 69.80 98.57 1817.63 1722.63 250.518 1662.30E 5959441.65 551964.78 0.00 -183.89 2900.00 69.80 98.57 1852.16 1757.16 264.498 1755.10E 5959428.29 552057.66 0.00 -194.15 - 3000.00 1>9.80 98.57 1886.69 1791.69 278.488 1847.91E 5959414.92 552150.54 000 -204.42 3100.00 69.80 98.57 1921.22 1826.22 292.46S 1940.71E 5959401.56 552243.43 0.00 -214.69 3200.00 69.80 98.57 1955.75 1860.75 306.458 2033.51E 5959388.20 552336.31 0.00 -224.95 3300.00 69.80 98.57 1990.28 1895.28 320.448 2126.31E 5959374.84 552429.20 0.00 -235.22 3400.00 69.80 98.57 2024.81 1929.81 334.428 2219.11E 5959361.47 552522.08 0.00 -245.48 3500.00 69.80 98.57 2059.34 1964.34 348.418 2311.91E 5959348.11 552614.96 0.00 -255.75 3565.62 69.80 98.57 2082.00 1987.00 357.588 2372.81E 5959339.34 552675.91 0.00 -262.49 Too K-15 3600.00 69.80 98.57 2093.87 1998.87 362.398 2404.71E 5959334.75 552707.85 0.00 -266.02 3700.00 69.80 9857 2128.40 2033.40 376.388 2497.51E 5959321.39 552800.73 0.00 -276.28 3800.00 69.80 98.57 2162.93 2067.93 390.368 2590.32E 5959308.02 552893.61 0.00 -286.55 3900.00 69.80 98.57 2197.46 21 02.46 404.358 2683.12E 5959294,66 552986.50 0.00 -296.81 -- 4000.00 69.80 98.57 2231.99 2136.99 418.338 2775.92E 5959281.30 553079.38 0.00 -307.08 -- 4100.00 69.80 98.57 2266,52 2171.52 432.328 2868.72E 5959267.94 553172.27 ......!LQQ -317.35 4182.48 69.80 98.57 2295.00 2200.00 443.858 2945.26E 5959256.92 553248.88 0.00 -325.81 103/4" Casino pt, 4200.00 69.80 98.57 2301.05 2206.05 446.308 2961.52E 5959254.58 553265.15 0.00 -327.61 -- 4300.00 69.80 98.57 2335.58 c....22~0. 58 ..AQQ.2f18 3054.32E 5959241.21 553358.03 000 -337.88 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48,30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL eonocJ'Pt,illips . ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit,North Slope, Alaska . PROPOSAL LISTING Page 3 Wellbore: 114 Well path: 114 Verso #2 Date Printed: 9-Aug-2004 .Jr: INTEQ WellDath ReDort MD[ft] 'nc[deg] Azi[ deg] ND[ft] Vertical North[ft] East[ft] 8tation 8tation Dogleg Vertical Station Comment Depth 88 Position(Grid Position(Grid [deg/10 Section[f - .~--- ~~~----~ ~-.~.- ~-------- ~-~---~" ---- N~à~,____ ~aÆL Oftl tL__ --~-~--~-_._--~-~--~. -- _ 4400JJCL I--º,!; ~ªº-- _9MZ_ _~:3ZQ11 __zm:¡,_lt __"ZA27~_ 3JAZ,~j; ~~922Lª9_ _553_450.92_ -Q...Q-º- :~,ª,H- _.~___.._______.,_.____.~_._,._~_~.._ __,___.'_____..____..__m_______ 4500.00 69.80 98.57 2404.64 2309.64 488.268 3239.93E 5959214.49 553543.80 0.00 -358.41 4600.00 69!;!JL.. __Ä~_, ..2431Llº 23~,11L 502.258 ~Z~ _ 5959201.12_ 1-..953636,!39 0.00 -368.68 _._--~-_.__._-----_._----------- 4700.00 69.80 98.57 2473.69 2378.69 516.238 3425.53E 5959187.76 553729.57 0.00 -378.94 4800.00 69.80 98.57 2508.22 2413.22 530.22S 3518.33E 5959174.40 553822.46 0.00 -38921 1---4-900.0Q... __ 69.80 .._ªª,QL 254£.7A _.244LZQ. 544.208 3611.14E 5~59161J)~ 5539...lli.34 0.00 -399.48 -------~------- 5000.00 69.8Q~ _, 98.57 2"':>77.27 2482.27 558.198 ...RQ3.94E 5959147.67 554008.22 0.00 -409.74 ._-- MOO.OO f-69.80 98.57_ .2Q11,ª-Q. 2516-ª.0_ _§7~j88 ~796 74.ç ~J.l4~ll.. _ß54101.11 0.00 -420.01 -~.,-- 5200.00 69.80 98.57 2646.32 2551,32 586.168 3889.54E 5959120.94 554193.99 0.00 -430.28 5280.47 69,80 98.57 2674.11 2579.11 597.428 3964.22E 5959110_19 554268.74 O.OQ -438.54 Start 200' Pump Tanoent -- , 5300.00 69.80 98.57 2680.85 2585.85 600.1Q~ ~1.!2.39j; 5959107.58 554286.88 0.00 -440.55 -- 5400.00 69.80 98.57 2715.38 2620.38 614.148 4075.15E 5959094.21 554379.76 0.00 -450.81 5480.47 69.80 98.57 2743.16 2648.16 625.398 4149.83E 5959083.46 554454.51 0.00 -459.08 BldlTrn 5/100, End 200' Pump Tangent, -- C----- . BldlTrn 4.5/100. 3DJ Kick off Point 5500.00 69.53 97.57 2749.94 2654.94 627.968 4167.96E 5959081.01 554472.66 5.00 -460.92 5600.00 68.24 92.39 2785.98 2690.98 636.088 4260.85E 5959073.52 554565.59 5.00 -465.32 5700.00 67.12 87.13 2823.99 2728.98 635.718 4353.31E 5959074.51 554658.04 5.00 -461.25 5800.00 66.17 81.78 2863.66 2768.66 626.858 4444.65E 5959083.98 554749.30 5.00 -448.75 5900.00 65.40 76.36 2904.70 2809.70 609.588 4534.15E 5959101.85 554838.68 5.00 -427.92 5924.67 65.24 75.01 2915.00 2820,00 ...§MQ3S 4555.87E 5959107.54 554860.36 5.00 -421.51 Too UQnu C 6000.00 64.83 70.88 2946.80 2851.80 584.028 4621.14E 5959127.99 5549?5.49 - 5.00 -398.90 6100.00 64.47 65.36 2989.64 2894.64 .Jj50.378 4704.97E 5959162.19 555009.08 5.00 -361.93 6200.00 64.31 59.82 3032.89 2937.89 508.888 4784.98E 595920421 555088.80 5.00 -317.28 6300.00 64.37 54.27 3076.22 2981,22 459.888 4860.57E 5959253.71 555164.06 5.00 -265.30 6400.00 64.63 48.74 3119.30 3024.30 403.738 4931.18E 5959310.33 555234.28 5.00 -206.37 6441.43 64.80 46.46 3137.QQ -ªº"Z~ 00 378.478 4958.84E 5959335.76 555261.77 ~lJ.Q. -180.03 Top Uonu B 6500.00 65.10 43.24 3161.81 3066.81 340.868 4996.25E 5959373.62 555298.93 5.00 -140.95 6600.00 65.76 37ZL 3203.42 3108.42 271.768 5055.3{)];, _..995.9443.12 555357.50 5.00 -69.54 6633.26 66.03 36.00 3217.00 3122.00 247.488 5073.52E 5959467,51 555375.56 5.00 -44.56 Too Uonu A 6700.00 66.62 32.41 3243.81 3148.81 196.938 5107.87E 5959518.28 555409.57 5.00 7.32 6800.00 67.66 27.10 3282.68 3187.68 116.978 5153.57E 5959598.54 555454.72 5.00 89.05 6900.00 68.87 21.88 3319.73 3224.73 32.468 5192.04E 5959683.29 555492.63 5.00 175.02 7000.00 70.24 16.75 3354.68 3259.68 55.93N 5223.00E 5959771.89 555522.99 5.00 264.59 7052.22 71.01 14.10 3372.00 3277.00 103.41N 5236.10E 5959819.45 555535.77 5.00 312.55 K-13 7100.00 71.75 11.70 3387.26 3292.26 147.55N 5246.20E 5959863.65 555545.58 5.00 357.06 7200.00 73.39 6.75 3417.22 3322.22 241.69N 5261.48E 5959957.88 555560.23 5.00 451.73 7291.77 75.00 2.29 344223 3347.23 329.68N 5268.43E 5960045.91 555566.58 5.00 539.93 EOC End of BuildlTurn -- 7300.00 75.00 2.29 3444.36 3349~~fL ~L63N í29/J.74E 5960053.86 555566.84 0.00 547.89 7400.00 75.00 2.29 3470.24 3375.24 434.15N 5272.6ûE 5960150.3JL ~55570.05 000 644.48 7491.80 75,00 2.29 3494.00 3399.00 522.75N 5276,14E 5960239_00 555573.00 0.00 733.15 Top West 8ak D, W8 1E C6 D TOP RVSD080304 End of Hold 7500.00 75.0{L 2.29 3496.12 3401.12 530.66N 5276.46E 5960246.92 555573.26 0.00 741,07 -- 7588.31 75.00 2.29 3518.98 3423.98 615.89N 5279.86E 5960332.16 555576.10 0.00 826.37 Build 3/100 End of Hold 7600.00 75.35 2.29 3521.97 3426.97 627.19N 5280.31E 5960343.45 555576.47 3.00 837.67 7658.97 77.12 2.29 3536.00 3441.00 684.42N 5282.60E 5960400.69 555578.37 3.00 894.95 C 7700.00 78.35 2.29 3544.71 3449.71 ]24.48N 5284.20E 5960440.76 555579.71 3..QQ... ~;35.04 7754.81 80.00 2.29 3555.00 3460.00 778.27N 5286.34E 5960494.56 555581.49 3.00 988.87 EGC. End of BuildlTurn 7783.58 80.00 2.29 3560.00 3465.00 806.58N 5287.47E 5960522.87 555582.43 0.00 1017.20 Top West 8ak B 7800.00 80.00 2.29 3562.85 3467.85 822.74N 5288.12E 5969539.03 555582.97 0.00 1033.38 7900.00 80.00 2.29 3580.22 3485.22 921.14N 5292.05E 5960637.45 555586.24 0.00 1131.86 -- All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR'G'~fA.L c.onocJPt,illips . ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 4 Wellbore: 114 Wellpath: 114 Verso #2 Date Printed: 9-Aug-2004 .Jr: INTEQ Wellpath Report MD[ft] Inc[deg] Azi[ deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 SeCtion[f -- ---------- --~ ---------- ~~---- ----- North) ____ East) Oft! tL___ -~--~-~--'-'-'--- 8000.Qº- _ªQ~OO_ _ __2~~_ 25_9L§-ª __~11º2 5.!L _1019"§4N 5295.9_LÇ __5~§Q73~,8_Q _ 555589.§Q_ __MiL -12~ºc34 ------,--,------,-,----------------- 8019.69 80.00 2.29 3601.00 3506.00 1038.91N 5296.74E 5960755.24 555590.15 0.00 1249.73 A-4 r-ª1ºQ.OO 80.00 ~~!L 3614.95 _3519~ L1F.94N ~990E 59608342~L _355592.7L . O_OQ_ ~ßÆ -------~-,._,-~~---- ---~------ 8200.00 80.00 2.29 3632.31 3537.31 1216.35N 5303.82E 5960932.70 555596.04 0_00 1427_30 8300.00 80.00 229 3649.68 355468 1314.75N 5307.75E 5961031.11 555599.31 0.00 1525.78 8359.46 80.00 - _22jL 3660.00 3565.00 1373.2pl'l _5310.09E 5961089.63 555601.25 0.00 1584_33 A-3 8400.00 80_0º- _b29 3667.04 3572.04 1413.1t1f\L 5311.68E 5961129.53 555602.57 0.00 1624.26 -- -- 8500.00 80.00 ~- _::¡684.4~ 3t1ª-ML 1511.55N 5315.6J2E 5961227.95 555605_84 0.00 1722.74 8600.00 80.00 229 3701.77 3606.77 1609.95N 5319.53E 5961326.37 555609.11 0.00 1821.22 8700_ 00 80.00 2.29 3719.14 3624.13 1708.36N 5323.46E 5961424.BL 555612.37 0.00 1919.70 8779.85 80.00 2.29 3733.00 3638.00 1786_93N 5326.59E 5961503.36 555614.98 0.00 1998.34 Top West SakA2, 75/8" Csg. Pt., 75/8i Casino 8800.00 80.00 2.29 3736.50 3641_50 1806.76N 5327.38E 596152320 555615_64 _ 0 cº-º-.- 2018.18 8820_ 83 80.00 ?29 3740.1'1 3645_12 1827.26N 5328.20E 5961º~ 555616_32 0.00 2038.70 Aid 4/100 2DJ Kick off Point 8920.83 84.00 2.29 3754.03 3659.04 1926_18N 5332.15E 5961642.64 555619.61 4.00 2137.70 9020.83 87.99 2.29 3761.02 3666.02 2025_84N 5336.13E 5961742_31 555622_92 4_00 2237.44 9047_04 89.04 229 3761.70 3666.70 2052.02N 5337.17E 5961768.50 555623.79 4_00 2263_64 EOC End of Build 9100.00 89.04 229 3762.59 3667.59 2104.93N 533928E 5_961821.41 555625_54 0.00 2316.59 9200_00 89.04 229 3764.27 3669.27 2204.84N 534327E 5961921-33 555628_86 0.00 2416.58 9300.00 89.04 229 3765.95 3670_95 230474N 5347.25E 5962021.26 555632.17 0.00 2516.57 9400.00 89.04 229 3767-63 3672. 63 2404,65N 535123E 5962121.18 555635.49 0_00 2616.55 9500.00 89.04 229 3769_31 3674-31 2504.56N 535522E 5962221_10 555638.80 0.00 2716.54 9600.00 89.04 229 3770_99 3675.98 2604.46N 535920E 5962321_ 02 555642.12 0.00 2816.52 9700_00 89.04 229 3772.66 3677.66 2704.37N 5363.19E 5962420.94 555645.44 0.00 2916.51 9800.00 89.04 2.29 3774.34 3679.34 2804.28N 5367- 18E 5962520.86 555648.75 0_00 3016.49 ~- 9900.00 89.04 229 3776.02 3681~ 2904.18N 5371.16E 5962620_78 555652.07 0.00 3116.48 9958.26 89.04 2.29 3777.00 3682.00 2962.39N 5373.48E 5962679_00 555654.00 0_00 3174.74 Curve 3/100, WS 1 E C6 A2-MDPT#1 ~- RVSD080304 End of Hold 9975.93 89.07 2.81 377729 3682.29 2980.04N 5374.27E 5962696.65 555654.67 3.00 3192.40 EGC SIC Kick off Point 10000.00 89_07 2.81 3777.68 3682.68 3004.08N 5375.45E 5962720.69 5tj5655.69 0_00 3216.47 10100.00 89.07 2.81 3779.30 3684.30 3103.94N 5380.36E 5962820_58 555659.93 0.00 3316.45 10200.00 89.07 2.81 3780.92 3685.92 3203.81N 5385.27E 5962920.47 555664.17 0.00 3416.43 10300.00 89.07 2.81 -- 3782.55 3687.55 3303.67N 5390.18E 5963020_35 555668.41 0.00 3516.41 10400_00 89.07 2.81 3784.17 3689.17 3403.54N 5395.09E 596312024 555672.65 0.00 3616.40 10500.00 89.07 2.81 3785.79 3690.79 3503.41 N 5399.99E 5963220.13 555676.89 0_00 3716_38 10600.00 89.07 2_81 3787.41 3692.41 360327N 5404.90E 5963320.01 555681.13 0.00 3816.36 10700_00 89.07 2.81 3789_03 3694.03 3703.14N 5409,81E 5963419_90 555685,37 0_00 3916.34 10800.00 89.07 2.81 3790,65 3695.65 3803.01N 5414.72E 5963519JJL 555689.61 0.00 4016.33 10900.00 89.07 2.81 379227 3697.27 3902.87N 5419.63E 5963619.67 ~93.85 0.00 4116.31 11000.00 89.07 2.81 3793.89 369889 _Æ002.74N 5424.54E 5963719.56 555698.09 0.00 421629 11100.00 89.07 2.81 3795.51 3700.51 4102.60N 5429.45E 5963819.45 555702.33 0.00 431627 11200_00 89.07 2.81 3797.14 370213 4202.47N 5434.36E 5963919_34 555706.57 0_00 441626 11300.00 89.07 2.81 3798.76 3703.76 4302.34N 5439.27E 596401922 555710.81 0.00 451624 11400.00 89.07 2.81 3800.38 3705,38 440220N 5444.18E 5964119_11 555715.05 0.00 4616.22 11500.00 89.07 2.81 3802.00 3707.00 4502.07N 5449.09E 5964219.00 555719.29 0.00 471621 11600.00 89.07 2.81 3803.62 370M2- ~º1.94N 5454.00E - 5964318.88 555723.53 0.00 4816.19 11700.00 89.07 2.81 3805.24 371024 4701.80N 5458.91E 5964418.77 555727.77 0_00 4916.17 - 11800.00 89.07 2.81 3806.86 3711.86 4801.67N 5463.82E 5964518.66 555732.01 0.00 5016.15 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 229 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR'G\~,Lð, . c:.onoOOPhillips ConocoPhillips Alaska, Inc.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 5 Wellbore: 114 Wellpath: 114 Verso #2 Date Printed: 9-Aug-2004 ..: INTEQ Well MD[ft] -"-~-~_.~~- ----~-.,--- --- TVD[ft] Vertical North[ft] East(ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[f ______ Nº-å!:lL___ ~a-ª-~_ Qfil tL~__ ______________ 2.81 3808.00 3713_00 4872.00N 5467.27E 5964589.00 555735.00 0.00 5086.56 TD, 4 1/2 Liner Pt., WS 1 E C6 A2 TOE RVSD080304, 4 1/2in Casing, End of ___________ ________________ __________________ ______ _______________ ti9JLEnd otlun1________________ 11870.42 89.07 -~---_._- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL eonocJPhillips . ConoeoPhillips Alaska, Ine.,Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 6 Well bore: 114 Wellpath: 114 Verso #2 Date Printed: 9-Aug-2004 .J£: INTEQ Comments MDrftl T~_ l:_¡¡g[~____,_ !,/ortl1LftL___ CoaUTle01._______,_____________________,__,____,______________,__,___________ ____300.00_ ___~Qj)~ 00__ _ __,!W.QE__ -- _ _Q.Q.QJ'L __ KQE___ .- --~ __ _n ~--'-- --~---_.._-- -- -- ~.,,------ ,,--,.,.--- -- ---------~_.._- _ _ ___~___·~___..·___·__·M____ ---.------'.-------.-..-- __ 633.3L__ ___1>.3J.'º-4" __2j.3~__L _ _ _ __Ad2S_ _ ßldlImAllQ,Q____ -----~_._---~._.~._--.---- --- -, ~ ---~--- -- "-"-- .. --,~--~---^._---_._-_.__.._.-.._- ----_.-.-.-------_._----_._-------~----- 883.33 872 82. __ ___!:12.5i:tEw ,_ __.J~J~.P_s.....___ BIcj[[m§L1.Q1L___ _ -------_._----~~---~. --- ________'m.__ ---------- ----_.---~------_._- -.-----._-_._---._----_..._--_._--,------~ 1713.33 1442.41 653.86E 98.54S EOC ---.2001. N..._ 1542.00 __!:12.LQ2J;____ _,_13M7S '._, Sase f:.~f'!J1af.cQ::>'L_________________ _,______________w_____________w______ 2708.39 1786.00 1577.29E 237.70S TOD T-3 3565.62 2082.00 2372.81E 357.58S Too K-15 4182.48 _ 2295_00____ _ 294Q.26E___ 443.85$ 10 3/4" Cas¡ngEL______________~_______ 5280.47 2674.11_ __3964.22E__ ~ZA~S.__ ~r!200' Pum1>_lanQent_~_________ 5480.47 2743.16 ,..1149.831;.__ _625.~~ Bld/fm 5/tº-º___~________________~____________ 5480.47 2743.16 4149.83E 625.39S End 200' Pumo Tanoent Bldffrn 4.5/100 5924.67 2915.00 4555.87E __ 1--_....904.03S _ TOD UQnu C .---~~-~--~-- 6441.43 3137.00 4958.84E 378.47S Too l,&nu B ,-- 6633.26 3217.00 5073.52E 247.48S TOD Uanu A 7052.22 3372.00 5236.10E 103.41N K-13 7291.77 3442.23 5268.43E ~9.68N EOC - 7491.80 3494.00 5276.14E 522.75N TOD West Sak D --, 7588.31 3518.98 5279.86E 615.89N Build 3/100 7658.97 3536.00 5282.60E 684.42N C 7754.81 3555.00 5286.34E 778.27N EOC - 7783.58 3560.00 5287.47E 806.58N Too West Sak B 8019.69 3601.00 - 5296.74E 1038.91N A-4 8359.46 3660.00 5310.09E 1373.25N A-3 8779.85 3733.00 - 5326.59E 1786.93N T OD West Sak A2. 7 5/8" CSQ. PI. 8820.83 3740.12 5328.20E 1827.26N__ Bid 4/100 9047.04 3761.70 5337.17E 2052.02N EOC 9958.26 3777.00 5373.48E 2962.39N Curve 3/100 9975.93 377.7.29 5374.2.7E 2980.04N EOC 11870.42 3808.00 5467.27E 4872.00N TD. 4 1/2 Liner PI. All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR\G\NA ~Ilips . ConocoPhillips Alaska, Inc., Slot #114 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 7 Well bore: 114 Wellpath: 114 Verso #2 Date Printed: 9-Aug-2004 ..: INTEQ Taraets Name . NQál:!IfiL..~~ EastfftL__~ TVDLftl_~__ ..I-atitude________ Lonaltude ,- Eastina -' NOrthlno ,.,~ WS 1E C6 A2 TOE 4872.00N 5467.27E 3808.00 N70 18 50.1112 W149 32 53.8802 555735.00 5964589.00 _ RVSDO_803Q4-~ ~----_._._--- ~---_._-~._._..__._._... - ---. .---..-.---'.. ._--~-- -~~._._----------~------ ------~-~._-----~-_.~- -----.--------- --.._-_._~-~------- WS 1E C6 2962.39N 5373.48E 3777.00 N70 18 313311 W149 32 56.6563 555654.00 5962679.00 A2-MDPT#1 RVSD080304 --.. ---,--~----,-- ----_._-~---,--- ~~-.__._-~- -- ---,-,---------.----..----.---" ~-~-~---------~-- ------~--~- _._~ WS 1E C6 D TOP 522.75N 5276.14E 3494.00 N70 18 7.3381 W149 32 59.5453 555573.00 5960239.00 RVSD080304 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 2.29 degrees Bottom hole distance is 7323.08 Feet on azimuth 48.30 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL = 0 -800 0 (\ II E 0 -400 Q) ëõ 0 (f) -0 0400 ;0 -=- 800 GW .- '41200 ~ 171600 CJ 1:: ~ 2000 (1) 2 2400 .... I V 2800 3200 3600 4000 4400 .. 8fIIrø ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slcmt#ß pt #114 Well: 114 Well bore: 114 , I ! I ¡ ! RKB Elevation: 95' KOP 6.00 BldlTrn 4/100 18.00 Bld/Trn 6/100 32.00 44.00 DLS: 6.00 deg/100ft EOC Top T-3 Top K-15 10 3/4" Casing PI. 69.80 Start 200' Pump Tangent BldlTrn 5/100 65.40 Top Ugnu C 64.31 DLS: 5.00 deg/100ft 65.76 To~~pgD~~u A 67.66 70.24 K-13EOC 73.39 O~,c' s\ ~,,.3.\\ '\ QQ C -..¿j ,\o\' -.Ne ~~\\Ó &~~ ~ p..-Þ. p..:?> ~ ,\o\' -.Nes 1 <:>\\')' cs~' ~p..'2., -.Nes\ Sa: ,\o\' Conoc~iII¡ps rea e y: Date plotted: 3-Sep-2004 ¡lot reference IS 114. Ref well path is 114 Verso 1f2. Coordinates are in feet reference Slot #114 . I True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. I Rig Datum: Datum #1 I Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. . e 114L2 -1200 -800 -400 0 Seale 1 em = 200 ft 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot#114 (STRONG!) 400 800 _ 3200 - Q) .æ - 3360 ..r:: - Q. Q) C 3520 o :::0 - G1 - :z » r iij (J :e 3680 ~ Q) :J L.. l- I V "" o a:> " E () ID '" ¿¡, 3200 - - ~ 3360 'f'- - ..r:: ë. 3520 Q) C ñi 3680 (J t! Q) > 3840 Q) :J L.. I- 4000 I V .ii. 8AICIR HUGHES ---_.__.~.~._._-- INTEQ Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ConocoPhillips Alaska, Inc. Slot: Well: Wellbore: Slot #114 114 114 ðf..\ø.ce'fø.rß o\e,'f..o'? \('I-r;\?~\A ",\oðf.. gefl'ri 1? ,\o~;ø.",e ¿~\eò 0 ~¥-r_~~'fø.c~o\e,'f..O ¡¿~ \('I~~~~~ "'~ge~ eS\ sø.'\<- ~I'\\)\) C C ~ '(09\ '1 ,;;.J.\Ò ~osø.'\<-';; ..leS\ '(09'1' 3840 4000 ~ ç>\.. '\ \)\) ~oc 1 ~I?J' C"'%\Ò b.\ sø.¥- ~, \('Ie"'\ ,\0';> Conoc6'Phillips Created by: Planner Date plotted: 3-5ep-2004 Plot reference is 114. Refwellpath Is 114 Verso #2. Coordinates are in feet reference 51ot#114 . True Verticai Depths are reference Rig Datum. Measured Depths are reference Rig Datum, Rig Datum: Datum #1 Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. e 89.07 89.01 114L2 114L1 CurveË88° 320 480 640 Scale 1 cm = 80 ft 800 3680 3840 Top West Sak A2, 7 5/8" Csg. PI. ~r:fj 4160 1760 1920 2080 2240 2400 2560 Scale 1 em = 80 ft 960 1120 1280 1440 1600 1760 1920 2080 2240 2400 2560 2720 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot #114 89.07 89.01 Curve 3/100 EOC 2880 3040 3200 3360 3520 e 89.07 89.01 TD 4 1/2in Line 89.07 2720 2880 3040 3200 3360 3520 3680 3840 4000 4160 4320 4480 4640 4800 Vertical Section (feet) -> Azimuth 2.29 with reference 0.00 N, 0.00 E from Slot #114 4960 5120 5280 5440 è0'd ltllOl . . ConocoPhillips Alaska, Inc. QCatlon: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Q: We"; Wellbor !: TRUe NORTH ..,.;,\ ~:t 350 o 10 340 ;10 330 30 320 40 50 60 70 80 1 0 :;! 0 90 260 100 250 110 120 230 130 220 140 150 160 170 160 All dÐpth~ ~.hcwJ" ~rf:l 1Vlfat'\$lJI' ;'c:j d';'I)H'~ I~' ~lljIl'l:tnr~ W~II NormDJ Plnn" ' r~II...rl/n9 r~ylll'(l~r· F$';'1 D.te pleted : 3.&¡>-2004 c erenœ I!$ 1M W<!llþsth I. 11A Vote, ~2. Ço~"JI"a"'. afa 1,,1.01 1'0roI'0"'-8 81øt ;114 , T"III, V"dJ~1 £)4,1'111111 tI~l~ I'Mrl'r~IIr.." niu OttlUlU MClQsIIJr~d D¡)þll'~ ¡J(I) rllftJronee RI~ DQtum. R;~ D.tum: D.lum #1 Ri~ D.Lumla moon ose.lovol; 95.00 n. P'lot North t~ allgnod 10 1 H.U!:. Nl:ìrlh. è0/è0"d ££:£1£9è¿061 SdIllHdOJONOJ 60:£1 Þ00è-91-d3S · . ·Ltaker Hughes Incorporated Anticollision Report ..'.." Time: 14:36:02 ..." "' le: J Co.qrdlnate(NE) Rerer~ncl!: Well: 114, True North Vertlul (TVD) Reference: Wellhead(95') 95.0 _ _ Db, ~~., is~~~~PLANNËD PRooRAM I Trav Cylinder North Ellipse ~__,.,.. ,...1'-·'_ " .. :::y~ - :::::.", $"<""" G~ _'" "'" "..;J...." MWD+SAG+IFR MWD"'SAG+I~R (AK) ~ ~ '"'' .......',. ~".,.," CllmpBOY: ConocoPhlllips Alaska, Inc. Field: Kuparuk River Unit R2ference Site: Pad 1 E Reference Well: 114 Ø,ererenclI Wcllp.th: 1E-114 Vers#2 UNO GLOBAL SCAN:u;i~;~~er denlle.ísele;tJon" Ican crlt~';I' InterpohitloD Method: MD Interval; 25.00 ft Depth Range: 0.00 10 11870.43 ft Ma11mum Radlu~: 5280,00 ft ..., ..,',.~'I·I- ." Date: .....II~ 'OJ .... ......... Sur'lle)' Pro~ram for Dennltl'lle WeUpath Date: 12/9/2003 Validated: No planned from To Sunil)' ft ft ~"'- -......,- 0.00 800,00 Planned: 1E-114 VerS#2 V28 800.00 11870.43 Planned:1E-114V8rs#2V28 IIn..... Summary < Site Off let WellpBtb Well .. "" Pad 1C Pad 1C Pad 1D Pad 1D Pad 1D Pad 1E Pad 1E Pad 1E Pad 1 E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1 E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1 E Pad 1 E Pad 1E Pad 1E Pad 1 E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E Pad 1E ,--, 104 104 103 113 116 105 105 105 112 112 112 112 114 114 117 117 117 119 123 123 123 126 126 126 168 168 168 21 22 23 24 24 25 26 215 33 33 .,'. .....-...... Þ0/G0"d S£S1S9G¿061 ,. ,. Wellpath Reference 1\1I0 ft 1C·104 VO 1 C·104L 1 V1 1D-103 V1 11866.90 1D·113V1 9999.90 1D·116 V1 8064.76 1E·105Vers#1.DV1 Pia 6841,93 1E-105L1Vers1,DV1PI 6841.93 1E-105L2 VeI"$1.D VO PI 6841.93 1E·112 V6 522.96 1 E-112L 1 V3 522,96 1E-112L2V2 522,96 1E·112PB1 V1 522.96 1 E·114L 1 Vers#2 V1 Pia 5750.00 1 E·114L2 VerS#2 V1 Pia 5750.00 117 A2-Lateral VO Plan 299,99 117 B·Lateral VO Plan: 299.99 117 D-Lateral VO Plan; 299.99 119VOPlan:1E·119ve 299.99 1 E-123 L1 V2 11853,05 1E-123 V18 11848.62 1E-123PB1 V1 11848.82 1E·126 V5 4700,50 1E·126L1V2 4700.50 1E·12ß1.2 V3 4700.50 11:-168 Vers#2 V3 Plan: 425.97 1 E-168L 1 Ver#2 VO Plan 425.97 11::-168L2 ver#2 VO Plan 425.97 1E-21 VO 568.27 1E·22 VO 1322,78 1 E-23 VO 448.20 1E-24 VO 423.07 1 E·24A va 423.08 1E·25 VO 424.67 1E-26 VO 499.$1 1E-26A va 499.81 1e-33 VO 449.35 1 E-33PB1 VO 449.35 ,., 8131/2004 -.'."'" Offset MD it 7825.00 6800.00 6025.00 7050.00 7050.00 7050,00 525.00 525.00 525,00 525.00 5750.00 5750.00 300.00 300,00 300.00 300.00 8300.00 8300,00 8300.00 5200.00 5200.00 5200.00 450.00 450.00 450.00 575.00 1375.00 450.00 425,00 425.00 425,00 500.00 500.00 450.00 450,00 Reference; Error Modl:l: Scan Method: Error Surface: çtr-Ctr No-Go Dl5tllnee Area ft it 561.35 978.46 1092.17 166.86 166.88 166.88 103.27 103.27 103.27 103.27 1,09 1,09 80.62 80.62 BO,62 120_68 1115.96 1118.16 1118.16 436.08 436.08 436.08 511.00 511.00 511.00 262.24 113.91 141.78 7B.05 78.05 20,78 40,04 40.04 35.57 35.57 SdIllHdOJONOJ 263,01 267.67 138.44 148.82 148,83 148,83 9.29 9.29 9,29 9.37 354.89 354.89 4,75 4,75 4.75 4.75 323,73 326,14 328.36 235.78 235,78 235.78 7.64 7.64 7.64 9,80 26.90 7,38 (j,89 6.89 6.91 8.41 8,41 7.86 7.S8 ._, ~. -,~ Allowable DI!'IIlatlon Warolng ft -....-.,'" 298.34 710.79 953.73 18.06 18.05 18.05 93,98 93.98 93.98 93.89 -353.80 -353.80 75.87 75.87 75.87 115,92 792.23 190.02- 789.80 200.31 200.30 200.30 503.36 503.36 503.36 252.44 87_01 134.41 71,16 71.16 13,87 31.64 31.64 27.69 27.69 ....... ....... Out of r~n9è Out of range Pass: Major Risk Pass; M~ior Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass; Major RIsk p~S$: Major Risk Pass; Major Risk Pass: Major RIsk Pas¡¡; Major Risk PAIL: Major Risk ~AIL; Major R¡,¡¡k Pass: Major Risk Pas<I: Major Risk P~IõS: Major Risk Pass: Major Risk Pass; M~jor Risk Pa¡¡¡¡¡¡: Major Risk J'>asl!;: Major Rilõk Pass; Ml'ljor Risk Pass: Major Risk Pass: Major Rì!õk F'ass: Major Risk Pass: Major Risk Pass; Major Risk Pass; Major Risk p~$S; Major Risk Pass: Major Risk Pass; Major Risk Pass; Major Risk Pass; Major Risk Pass; Major Risk Pa$!õ: Major Risk Pat;S; Major Risk Pass; Major Risk .... .....- 8G:S1 Þ00G-91-d3S . -- co.,..»)': Field: Reference Slte~ Reference Well: Reference WeUpath; . . uaker Hughes Incorporated Anticollision Report ""Ylmew: ø 111~. :14134:44, Tn,a North -_..,,'-~ Page: I 1 Co-ordln..te(NE) Ibference: u , .... Vertical {TV D) Reference: Wellhead(9S') 95.0 Db: Oracle -- p,"""., PI," ÚLÃNNED PRóGAAM ~ ISCWSA Ellipse Trav Cyllndar North Ellipse -- - _. ~ - Datt; 8/3112004 ConocoPhilllps Alaska, Inc. Kupal1.lk RI"ar Unit Pad 11: 114 1E-114L1 vers#2 "'~~ ........ ..."... ,....- ... GLOBAL SCAN APPLIED: All wellpath$ within 100'+ 100/1000 of reference Interpolation Method: MD Interval; 25.00 f\ Pepth Ran¡:c: 1'r83.60 to 11654.46 f\ Maximum Radills: 5280.00 f\ ...,.... -'- Survey Program for Dcfinitive Wellpath Date: 6/31/2004 Validated: No Planned From To Survey n It --". 1783.60 11654.46 -.. .'- Version: l'ooléode 2 Planned: 1 E.-114L1 Vers#2 VB MWD+SAG""FR ,- Summáry < - OlT,et Wellpatb - SIt2 Well .. -.. Pad 1 B 15 Pad 16 15 Pad 16 17 Pad 1 a 18 Pad 18 4 Pad 18 6 Pad 1E 112 Pad 1E 112 Pad 1 E 112 Pad 11: 112 Pad 1E 114 Pad 1E 114 Pad 1 e: 117 Pad 1E 117 Pad 1E 117 Pad 1E 119 Pad 1E 22 Pad 1E 23 Pad lE 24 Pad 11: 24 Pad 1E 25 Pad 1E 26 Pad 1E 26 Pad 1 E 33 Pad 1 E 33 .-- ....n 170/[0"d S~ST£9ë:¿06T _..',.~I·--· 6475,00 1629.99 289,81 1340.18 6200,00 1740.B9 304,26 1436.62 6400,00 625.93 216,93 409.00 6025.00 630.68 306.41 324.28 6175.00 1498.42 256.15 1240.27 6600.00 1266.23 259.72 1008.52 ~ Wellplth Ref\!renec MD ft Ofhet MD tt. 114,1E-114L1 Vers#2.1Ë 1B-15VO 11645,66 lB-15A VO Pial"!: 1B·15A 11650.44 18-17 V2 11847.42 18-16 VO 11557.72 18-04 VO 10353.24 1B·06 VO 10183.43 1E-112 V6 lE-112L1 V3 11:-112L2 V2 1E·112PBl V1 lE-114 VerS#2 V6 Plan: 1E-114L2 Vers#2 V2 Pia 11774.76 11848,60 117 A2-Lateral VO Plan 117 B-lateral VO Plan: 117 D-Lateral Vo Plan: 119 VO Plan: lE-119 Ve 1 E-22 VO 1E·23 VO 1 E·24 VO 1 E·24A VO lE-25 VO lE-;2.6 VO 1 E-26A VO 1 1:"33 VO 1 E-33PB1 VO ..~,... Referencc: Error Model: Scan Method: Error Surface: ··..·....."1'''-- Tool Name .-... .." MWD"SAG+Ii=R (AK) "-'" _.. ..111."·' -~ Ct.--Co' No-Go Distance Mea ft ft Allowable Deviation Warning ft .,,~ Out of rangQ Pass: Major Risk Pass: Major Risk Pass: Major Rlt;k Pa$; Major RIsk Pa55: Major Risk Par;¡s: Major Risk Out of range Out of range Out of range Out of range Out of range 46.79 121.74 -74.95 FAIL: Major Ri$k Out of range Out of range Out of range Out of range Out of range 01,11 of range Out of range Out of range Out of range Out of range Out of range Oul of range Out of range - ...", -,' SdIllHdOJONOJ 8ë::£1 1700ë:-91-d3S Þ0"d ltl101 . . .uaker Hughes Incorporated Anticollision Report - -.. ~~;;~=~:hH~;':;;~j,~rth -:~~J -- Principal Plan"¡"·P't.ÃNNED PROGRAM..] ISCWSA Ellip36 Trllv Cylinder North Ellipse _.__._. ....,,_ T~IN'-: U__~U~------¡. MWD+SAG+IFF't (AK) ----j Referl:nrt: Error Model: Sclln Methðd: Error Surface: Company: FIeld: R"r"tltn~e Site: Referent" Well: Rerl!T,mœ Wel~~atb: ConocoPhllllps Alaska, In.:. Kuparuk River Unit Pad 1e 114 1E-114L2 Vera#2 ..- .. .......,..., GLOBAL SCAN AI'I'LlED: All wellpatbs wltbln 10tl'+ 100/1000 of reference Interp(llatl(lD Method: MD Interval: 25.00 ft Depth Range: 7491.81 to 111:148.60 ft Mulmum Radius: 5280.00 It ". Survey Program tor Derinltlve WeUpath Date: 8/31/2004 Valla.ted: No Planned I'rom To Survey ft ft 7491.81 11648.60 Ver~lol'I; "tooleode 2 ,- Planned: 1 E:·114L2 Vers#2 V9 MWD+SAG+IFR -- -" Summary _........."....".-- < Offset Wellpflth ~ Reference Offset Ctr-Crr No-Go Allowable Sl~ Well WeUpath MD MO Dl5ta:llee Area Deviation W...nlng ft ft ft It 1t ........ ,-....- Pad 1 a 15 1B-15 VO 11/347.89 6650.00 1715.63 269.13 1426.50 Pa55: Major Risk Pad 1ß 15 1B-15A VO Plan: 1B-15A 11837.45 6350.00 1845.34 308.47 1536./37 Pass: Major Risk Pad 1B 17 18-17 V2 11844.10 6575.00 738.20 212.91 525.30 Pass: Major Risk Pad 18 18 18·18 VO 11605.75 6075.00 63~.S; 309,89 323.08 Pass: Major Risk Pad 16 4 16-04 vo 10399.23 6225.00 1510,33 260.87 1249.45 Pass: Major Ri5k Pad 16 6 16-06 VO 10216.54 6615.00 1282.25 263.08 1019.17 Pa!;s: Major Risk Pad 1E 112 1E·112 V6 Out of range Pad 1E 112 1 E:·112L 1 V3 Out of range Pad 1 E 112 1 E-112L2 V2 Out of range Pad 1E 112 1E-112PB1 V1 Ol,lt of range Pad 1E 114 1E-114 Vers#2 V6 Plan; Out of range Pad 1¡;: 114 1E·114L1 Vers#2 V2 Pia 11848.60 11775.00 46.79 1<11.73 -74.94 FAIL: Major Risk Pad 1 E 117 117 A2·Lateral VO Plan Out of range Pad 1E 117 11713-Lateral VO Plan: Out of range Pad 1E 117 117 (I-Latel'lll VO Plan: Out of r.ønge Pad 1E 119 119 VO Plan: 1E·119 Ve OI.Jt of range Pad 1e 22 1 E-22 VO Out of range Pad 1 e 23 1E-23 VO Out of range Pad 1E 24 1 E:-24 VO Out of range Pad 1E 24 1 E-24A VO Out of range Pad 1 E 25 1 E-25 VO Out of range Paa 1E 26 1 E-26 VO Out of range Pad 1 E 26 1 E-26A VO Out of range Pad 1 E 33 1 E·33 VO Out of range Pad 1E 33 1E-33PE'!1 VO Ol,It of range ",,,- - ...". -......-- Þ0/Þ0'd S£STS9c¿06T SdIllHdOJONOJ Bc:ST Þ00c-9T-d3S · . lE-114 Drilling Hazards Summarï 131/2" Open Hole 1103/4" Casing Interval Hazard Risk Level Mitiaation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Control drill, Reduced pump rates, Reduced ,/ drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets), pumpinq out 9 7/8" Open Hole I 7 5/8" Casing Interval Hazard Running Sands and Gravels Risk Level Moderate Stuck Pipe Low Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low Low Moderate Miti ation Strate Maintain planned mud parameters, Increase mud weight, use weighted swee s. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht / BOP training and drills, increased mud wei ht. Reduced um rates, mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets, um in out 6 3/4" Open Hole I 4 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Low Lost Circulation Hole Swabbing on Trips Moderate Low Miti ation Strate Stripping drills, Shut-in drills, Increased 1/ mud wei ht. Good hole cleaning, PWD Tools, Hole o ener Decreased mud wei ht Reduced um rates, Mud rheolo ,LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out 1E-114 Drilling Hazards Summary prepared by Steve Shultz 9/1/2004 4:24 PM ORIGINAL Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift KOP: 300', build at 3-5 deg/100' Top of Cement: 5,500' Top of Ugnu: +1- MD 13-1/2" Hole, 10-3/4" Çasing, 4,182' MD, 2,295' TVD 'D' Sand Lateral D-sand Casing at 7,492' MD un West Sak 7...5/8n Injector 1 E..114 Tri..Lateral Com pletion Intermediate and all laterals are be drilled with Rotary Steerable. 6-3/4" Hole, 4-1/2" Liner Set @ 11,849' MD, 3,574' TVD Tangent Angle: 70 deg 'B' Sand Lateral B-sand Casing Exit at 7,784' MD 6-3/4" Hole, 4-1/2" Liner Set @ 11,854' MD, 3,633 TVD 'A' Sand Undulating Lateral 6-3/4" Hole, Set @ 11,870' MD, Rev!slonNo" KRU 1E-114 2041710 SFD 9/1472004 . . . 5 ~ o ~ 200Whn. clay c.""" "'. N...",~ DE 19111 Valid Up T o5000Dòllars ~~o~ 0 oDD 01,1,,: 20111,? 0'10 ?"'2?~~d~ , c III ¡. 0 b b / f UNN€RSAL . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER k/2t( IE -/1/ ~Óc/r 17 ( WELL NAME PTD# Development v Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE". APPLIES (OPTIONS) MULTI Tbe permit is for a new we1Jbore 'segment of LATERAL existing well . Permit No, API No. . (If API num ber Production. sbould continue to be reponed as last two (2) digits a function' of tbe original API number. stated are between 60-69) above. Pn.,OT HOLE In accordance witb 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot bole must be clearly differentiated In botb name (name on permit plus PH) .' and API Dumber (SO - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ,to fuD EXCEPTION compliaDce witb 20 AAC 25.055~ Approval to perforate aDd produce is contingent upon issuance of ~ conservation order approving a spa dng exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals tbrougb target zones. .' Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-114 Program SER Well bore seg D COPHILLlPS ALASKA INC Initial Classrrype ----.SER I PEND GeoArea 890 Unit 11160 ~ On/Off Shore On ~ Disposal D Administration Permit fee attached _ _ _ - - - - - - Yes - - - - - - - - - - - - - - - - - - - - 2 _Lease _numberaPRrORriate - - - - - _ _ _ _ _ _ _ Yes_ Surface Ipçation an_dJQP_ Rroductive jnteJllaJ in ADL025651 - - - - 3 _Unique well_n_ame_a(1CI Iwmb_er _ _ _ _ _ _ _ _ _ . _ _ _ . _ . _ _ _ - - - - _ _ _ _ _ _ _ _ Yes __ - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - -- 4 Well JQc¡;¡ted in.a. d_efined .ppol. - - - - - - - - - Yes __ I~:B.U West Sak .Ojl PpQI. goyeroed byC.ooseJVatiQn QrderNo, 4Q6A_ . _ _ _ _ _ . - - - - 5 WelUQc¡;¡ted prpper .distaOÇ8_ from driJliog unitboundacy _ _ . . . _ . - - - - - - Yes_ - - - - - - - - - - - - - 6 WeJI JQcated prpper distaOÇ8_ from Qtber wells. Yes NQmioal spa_cing within the PQQI is.10 _acres._ - - - - - . - - - - - -- 7 S_ufficient acreage.aYailable indJilliog unjt _ - - - - - - - - . _. _ _ Yes_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Jfdeviated, js. weJlbQre plaUncJu.ded . Yes - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - .- 9 _O-perator only affected party. . - - - - - - - _ _ _ . _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - 10 _O-perator bas_apprppriateJ1.ond inJQrce _ _ . _ . . _ . _ _ _ _ _ _ - - - - _ _ _ _ _ _ _ _ Yes__ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - -- 11 Permit c.ao Þe issl!ed wjtbQut consel"llatic:>n order_ - - - - - _ _ _ . . . . _ _Yes_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . Appr Date 12 Permitc_ao Þe issu.ed witbo_ut administratÎlle_apprPllaJ . _ . _ _ _ . Yes _ - - - - - - - - - - - - - - - - - -- - - - - - - - - - SFD 9/15/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUQcated within area ªnds1rataauthQrized by.lojectipo Order # (putlO# in_cDmmeotsUfQr. .Yes _ - Area InjeçtionQrder Np._2B - - - - - - - - - - - - - - - 15 AJI weils_within Jl4J'uile_area_of reyiew ideotlfied (Fpr$.ervjce_w_ell onlYL _ _ _ _ _ _ . . _ _ . _ _ _ Ye:L - I~HU 10- ~ 12, !<RU J D: 1J 3,XRU_ tQ-1l6~ ~R.U 11;- j 23. _KRU_ tE.:- t2~1. t, !<RU J D: 1.o::L - - - -- 16 Pre-produçed iojßctor; duration of prß--production les$. than. 3 months. (for_sßrvice well QnJy) . Yes. WilLbe -pre.:-RrQd_ucedJor_2.to 6 months._ _ _ _ _ _ . - - - - - - - - - - - - - 17 _ACMP.F:indingof CQnsi$teocyhas ÞeenJ~suedJorJbis project. . _ _ _ _ _ _ _ NA. _ WßiI will be drilled fJQm an exjs1iog pad. - - - - - - - - - - - - - - - Engineering 18 _C.olJduçtor stril1g.prQvidßd _ - - - - - - - - - - - - -- yes_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 _S.u (face _casing. pJQtect~ alLknown USDWs _ . - - - - - - - - - NA. _ AllaCl-uifer~ex_empted,40C.FR1~7,jQ2(b)(3).. _ _. _... - - - - - - - - - - - . - - - - 20 _CMT vol adßQuateJo circulate_on.cond.uctor & surfC$g _ . . _ . . _ _ _ . _ . . _ _ Y_es_ - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 21 _CMT vDI adeQuate_ to tie-inJQng _striOg to.s!Jrf ~g_ . . _ . - - - - - - - No All hydrocarbQn_zPoes_will be.cpvered, _ - - - - - - - - - - - - - - - - - 22 _CMTwill coyera]l known.pro_ductiye bQri¡ons - - - - - - - - No Slotte_dJioercompletloo plaoned. - - - - - - - - - - - - - - - - - - - - -- 23 _C_asiog de_sigos ad_equate fpr C,T. B&permafrost _ _ _ _ _ . _ _ Yes. - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - - - - - 24 Adequate Jan}l.age OJ reserve pit _ _ _ _ _ _ . - - - - - - - - - - - -- . _ . .Yes. 8,ig is. e_quippedwith steeLpits. . NQ rßsel"l1e_pjt-plaooed, All waste to_an _apprOlledaonuJu$.or Class.!1 wel 25 JtaJe-drill" bas.a. to,403 for abandQnment beeo apPJQvßd . - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequatewellbore separatjo-"_pro-posed. _ _ . _ . _ _ _ _ _ _ _ _ - - - - . - _ _ _ Yes__ I?rp~imity- analysi$ pertorme.d, Jraye1ing cylioer -plot includ_ed._ Gyros PQssible._ _ . _ _ _ _ _ _ _ _ _ 27 Jtdivßrter JeqJ,lired, dQes it meßt fßguJations - - - - - - - Yes. _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e Appr Date 28 _DJilliog fluid prQgram $chematic& eCl-uip Jistadequate _ _ _ _ . Yes_ 61-11:> ex-pected beiwe_eo8.6 - 9.0 EMW. .F'lanned MW 9.3 pp.gJQrJntermediatß hQle and_lIVest Sak. TEM 9/16/2004 29 _BOPEs,.d_oJhey meßtreguJation _ _ _ _ _ . . - - - - - - - - - - - - - _ _ Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~~l (p 30 _BOPEpress ra.1iog appropriate; Jest to (put psig in_comments). . .Y~s_ MASF' calcula1e_d_a11246 -psi, CPAt Rlans.1Q tßst tQ 5000 psi.. . . . - - - - - - - - 31 Choke_manjfQld cQmpJie$. w/APIRF'-53 (May 84). _ . . _ . - - - - - Xes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 WQrk will occ_ur withoytoperationsbutdow.n. _ . _ _ - - - - Yes - - - - - - - - - - - - - - - - - - - -- - - - - - - - - 33 J~ pre~eoce_ Qf H2S gas prQbaÞ\ß . - - - .. - - - - - - - - - - - No_ __ H2S is ~oltkely.. Mud ~hould pr_eclude_ H2S o_nthe. rig, Hig is equjpped with_ s_eosors. and alarms.. 34 Meçbanicalcooditloo pfw~lIs within 808, yerified (For.s_ervice welJ onJy). Yes. Cementing repQrts _of 8QR wetls .e1Camioed, _Spme pperaltoo$. noJ ORtimal, buti~0Ia1iQn_ is lik.ely, Geology 35 Permit cao be issl!ed wfQ hydrogen_ s.ulfide meas~œs. . . _ . _ _ _ _ _ .Yes. - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - 36 D_ata.PJeseoted Qn_ R01ential pveJpre~Sure .zone.s _ . . - - - - -- _ _ _ Y_es EXPßcted resel"llojr -pre_ssuJe i$8,6-9,0_ p-pg EMW; wjllb~drilled wjtb 8.6 _- 9.~ -ppg mud. Appr Date 37 _Setsmic.analysis_ Qf sbaJlow gas_zpoes. NA - - - - - SFD 9/14/2004 38 _Seabed _condjtipo SUl"lley.(if Qf{-sh.ore) _ _ . .. _ _NA - - - - - - - - - - - - - 139 . CQnta_ct namelphoneJor.weßkly prpgre~sreports [explQratpryonly] . . . _ _ NA - - Geologic Engineering Date ~' Date Commissioner: Commissioner: . sioner e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 05/05/13 AWS 01 **** TAPE HEADER **** LDWG 05/05/13 01 *** LIS COMMENT RECORD *** . ! !!!!!! !!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!! !!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 3 C. WONG D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: Pm: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.625 6.750 . ~Î'I-h-! DRILLERS DEPTH (FT) 148.0 4198.0 8736.0 11857.0 fr/)/Å~ 1E-114 500292322300 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 13-May-05 MWD RUN PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR MWD RUN 4 4 F. WENDLER P. WILSON 16 11N 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 . . TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 2.2151" LONG: W149 DEG 35' 33.3755" LOG MEASURED FROM D.F. AT 98.4 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 148 to 4205 feet MD (148 to 2299 feet TVD). 2) Baker Hughes INTEQ run 3 utilized a 6.75" ATK 2.5 with Reservoir Navigation Resistivity (RNT) , Gamma Ray, along with Annular Pressure to drill from 4205 to 8741 feet MD (2299 to 3726 feet TVD). 3) Baker Hughes INTEQ run 4 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR) , Gamma Ray, along with Annular Pressure to drill from 8741 to 11857 feet MD (3726 to 3788 feet TVD). REMARKS : 1) Depth of 10 3/4" Casing Shoe - Driller: 4198 feet MD (2296 feet TVD). Depth of 10 3/4" Casing Shoe - Logger: 4198 feet MD (2296 feet TVD). 2) Depth of 7 5/8" Casing Shoe - Driller: 8736 feet MD (3725 feet TVD) . Depth of 7 5/8" Casing Shoe - Logger: 8732 feet MD (3725 feet TVD) . 3) The interval from 8710 to 8741 feet MD (3721 to 3726 feet TVD) was not logged due to 7 5/8" casing. Note: Due to the change in resistivity tool type (from RNT in the 9.875" borehole to MPR in the 6.75" borehole) the resistivity presentation goes from 2 curves (RNT: RPD & RPS) to 4 curves (MPR: RPD, RPM, RPS, RPX). 4) The interval from 11826 to 11857 feet (3785 to 3788 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 82 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4198.0 STOP DEPTH 11857.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- . . BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 3 4 MERGE TOP 4198.0 8710.0 MERGE BASE 8710.0 11857.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. Note: Due to the change in resistivity tool type (from RNT in the 9.875" borehole to MPR in the 6.75" borehole) the resistivity curves RPM & RPX are null in the 9.875" hole section above 8710' (MWD Run 3). $ # *** INFORMATION TABLE: CONS MNEM VALU -----------~~----------------------- WDFN LCC CN WN FN COUN STAT le-114 5.xtf 150 - ConocoPhillips Alaska, Inc. lE-1l4 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 . 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 495 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4198.000000 11857.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 541 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 2 .2500 START DEPTH 4150.0 STOP DEPTH 8710.0 # 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 VENDOR TOOL CODE PRES DIR RNT GRAM $ BOTTOM) TOOL TYPE PRESSURE DIRECTIONAL RES. NAVIG. GAMMA RAY RES. # BOREHOLE AND CASING DATA 01-0CT-04 MSB 18704 6.75 ATK MEMORY 8741. 0 4150.0 8710.0 o 66.5 80.2 TOOL NUMBER 100009727 10035313 1127 1127 . 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 9.625 4198.0 F.W. Spud 9.15 .0 .0 200 .0 .000 .000 .000 .000 108.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 3) . RNT/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-114.xtf 150 ConocoPhillips Alaska, I lE-114 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value=' 0) Datum Specification Block Sub-type is: 1 . FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 435 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4150.000000 8710.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 516 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!! !!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 3 .2500 START DEPTH 8710.0 STOP DEPTH 11857.0 # 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) 06-0CT-04 MSB 18704 4.75 MPR MEMORY 11857.0 8710.0 11857.0 o . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY PRESSURE RES. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 82.9 94.7 TOOL NUMBER 10031890 1033 10060365 10064653 6.750 8736.0 OBM 9.30 .0 .0 78000 .0 .000 .000 .000 .000 109.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWD Run 4). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-114.xtf 150 ConocoPhillips Alaska, I lE-114 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH GRAM RPCL RPSL RPCH 0.0 0.0 0.0 0.0 GRAM RPD RPM RPS .. . . RPSH RPSH RPX 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Unitð Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 407 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth units 8710.000000 11857.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 492 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/05/13 01 **** REEL TRAILER **** LDWG 05/05/13 AWS 01 .. Tape Subfile: 5 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes
