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Home My WebLink About197-077MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-26 KUPARUK RIV UNIT 3K-26 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 3K-26 50-029-22764-00-00 197-077-0 W SPT 6621 1970770 1655 1910 1910 1910 1910 540 670 630 620 4YRTST P Austin McLeod 12/26/2025 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 UNIT 3K-26 Inspection Date: Tubing OA Packer Depth 210 2810 2770 2760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251227122144 BBL Pumped:1.7 BBL Returned:1.7 Friday, January 16, 2026 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:NSK DHD Field Supv Cc:Regg, James B (OGC) Subject:RE: 10-426 form for 3K-pad SI non-witnessed MIT-IA"s 5-8-25 Date:Wednesday, June 18, 2025 2:28:23 PM Attachments:image001.png Matt/Bruce, I made a minor revision, changing the report date to 05/08/25. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK DHD Field Supv <n2238@conocophillips.com> Sent: Thursday, May 8, 2025 6:41 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: 10-426 form for 3K-pad SI non-witnessed MIT-IA's 5-8-25 Morning, Please see the attached 10-426 form from the 3K-pad SI non-witnessed MIT-IA’s that was performed on 5-8-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor .58. 37' KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861020 Type Inj N Tubing 1275 1275 1275 1275 Type Test P Packer TVD 6420 BBL Pump 1.2 IA 450 2030 1975 1950 Interval 4 Test psi 1605 BBL Return 1.2 OA 25 30 25 25 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861040 Type Inj N Tubing 1450 1450 1450 1450 Type Test P Packer TVD 6431 BBL Pump 2.0 IA 700 2010 1930 1910 Interval 4 Test psi 1608 BBL Return 2.0 OA 150 150 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861250 Type Inj N Tubing 1350 1360 1360 1360 Type Test P Packer TVD 6564 BBL Pump 1.6 IA 300 2030 2010 2000 Interval 4 Test psi 1641 BBL Return 1.6 OA 10 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861510 Type Inj N Tubing 1200 1250 1250 1250 Type Test P Packer TVD 6606 BBL Pump 1.2 IA 140 1900 1880 1880 Interval 4 Test psi 1652 BBL Return 1.2 OA 10 10 11 11 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980810 Type Inj N Tubing 1340 1350 1350 1340 Type Test P Packer TVD 6548 BBL Pump 1.0 IA 700 2040 2030 2030 Interval 4 Test psi 1637 BBL Return 1.0 OA 320 480 480 480 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1970770 Type Inj N Tubing 1080 1210 1100 1090 Type Test P Packer TVD 6621 BBL Pump 1.2 IA 220 1940 1915 1910 Interval 4 Test psi 1655 BBL Return 1.2 OA 540 620 580 580 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980820 Type Inj N Tubing 1340 1475 1425 1400 Type Test P Packer TVD 6117 BBL Pump 1.0 IA 100 2110 2080 2070 Interval 4 Test psi1529BBL Return1.0OA25252525 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980770 Type Inj N Tubing 820 840 840 840 Type Test P Packer TVD 6275 BBL Pump 1.3 IA 200 1800 1790 1790 Interval 4 Test psi 1569 BBL Return 1.1 OA 25 40 40 40 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 3K-31 3K-34 Notes: 3K-25 3K-26 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 3K-07 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3K Pad Gschwind/Sheets 05/08/28 Notes: Notes: Notes: Notes: 3K-02 3K-04 3K-18 Form 10-426 (Revised 01/2017)2025-0508_MIT_KRU_3K-26 9 9 9 9999 999 9 99 9 -5HJJ 3K-26 Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 13KͲ26 50Ͳ029Ͳ22764Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 16ͲJulͲ23 0 1 23KͲ27 50Ͳ029Ͳ22751Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 15ͲOctͲ23 0 1 33OͲ18 50Ͳ029Ͳ21793Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 19ͲNovͲ23 0 1 4WSWͲ06 50Ͳ029Ͳ20851Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 13ͲOctͲ23 0 1 5 6 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 3K-36 PTD: 197-077 T38175 2. 3K-27 PTD: 197-046 T38176 3. 3O-18 PTD: 188-026 T38177 4. WSW-06 PTD:182-177 T38178 12/1/2023 1 3KͲ26 50Ͳ029Ͳ22764Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 16ͲJulͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:13:24 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, October 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-26 KUPARUK RIV UNIT 3K-26 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/12/2023 3K-26 50-029-22764-00-00 197-077-0 W SPT 6621 1970770 1655 1050 1050 1040 1040 510 600 570 560 OTHER P Sully Sullivan 8/14/2023 MITIA per sundry #323-292 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 UNIT 3K-26 Inspection Date: Tubing OA Packer Depth 400 2030 1990 1985IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230816131538 BBL Pumped:1 BBL Returned:1 Thursday, October 12, 2023 Page 1 of 1           Post-tubing patch MIT 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11690'feet None feet true vertical 7013'feet None feet Effective Depth measured 11489'feet 10767', 10842'feet true vertical 6826'feet 6169', 6234'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 11270' MD 6622' TVD Packers and SSSV (type, measured and true vertical depth) 10767' MD 10842' MD N/A 6169' TVD 6234' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 6779' 4100' Burst Collapse Production Liner 11637' Casing 7001'11677' 6738' 122'Conductor Surface Intermediate 16" 7-5/8" 79' measured TVD 5-1/2" x 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-077 50-029-22764-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025519 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3K-26 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 122' ~ ~~ INJECTOR ~~ ~ 323-292 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 265-6471Senior Well Integrity Specialist 11374-11394', 11408-11428' 6719-6737', 6750-6769' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:21 pm, Aug 04, 2023 Digitally signed by Jan Byrne DN: OU=Well Integrity, O=Conocophillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.08.03 14:43:20-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 7/11/2023 ACQUIRE DATA PULLED 2.75" CA-2 PLUG FROM 11,262' RKB. BRUSH & FLUSHED TUBING W/ 98bbls OF DIESEL, FOCUSED ON D-NIP @ 11262' RKB & PATCH SETTING INTERVAL, JOB SUSPENDED FOR PRIORITY WORK. 7/15/2023 ACQUIRE DATA OPENED CMU SLEEVE @ 11,221' RKB. LRS PUMPED 200bbls OF SEA WATER & 25bbls OF DIESEL DOWN IA. CLOSED CMU SLEEVE @ 11,221' RKB,.SET 2.75" CAT STANDING VALVE IN D-NIP @ 11,262' RKB, LRS PERFORMED CMIT-TxIA @ 2500psi, PASSED, PULLED 2.75" CAT STANDING VALVE FROM D-NIP @ 11,262' RKB, IN PROGRESS 7/16/2023 ACQUIRE DATA RAN 2.72" x 40' DUMMY PATCH DRIFT TO 11,000' SLM. SET 2.725" P2P PACKER (CPP35356) @ 10,844' MID ELEMENT, IN PROGRESS 7/17/2023 ACQUIRE DATA RAN TTS TEST TOOL TO P2P PACKER @ 10,844' RKB, CMIT-TxIA @ 3000 psi PASSED. PULLED TEST TOOL, SET PBR/SPACER PIPE IN LOWER PACKER @ 10,844' RKB (41.37' OAL), RAN TTS TEST TOOL TO TOP OF SPACER, CMIT-TxIA @ 3000psi PASSED. PULLED TEST TOOL, IN PROGRESS 7/18/2023 ACQUIRE DATA SET UPPER 2.72" P2P @ 10769.28' RKB (CE) TOP @ 10766.83' RKB, MIT IA 3000 PSI (PASS). JOB COMPLETE. 3K-26 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 11,489.0 3K-26 12/11/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set 3 piece Patch across tubing leaks 3K-26 7/18/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: CONDUCTOR EXTENDED 14"TO STABLIZE WELLHEAD 6/19/2016 pproven NOTE: View Schematic w/ Alaska Schematic9.0 11/3/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 43.0 122.0 122.0 62.58 H-40 WELDED SURFACE 7 5/8 6.88 41.1 6,779.1 4,100.4 29.70 L-80 BTC PRODUCTION 5.5x4.5"@11291' 5 1/2 4.95 40.1 11,677.0 7,001.2 15.50 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.2 Set Depth 11,270.3 Set Depth 6,622.1 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.2 36.2 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 499.5 499.5 0.75 NIPPLE 4.540 CAMCO DS NIPPLE 2.812 11,220.8 6,576.2 22.17 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE (Closed 0715/23) 2.812 11,262.2 6,614.6 21.72 NIPPLE 4.540 CAMCO D NIPPLE 2.750 11,269.4 6,621.3 21.71 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,766.8 6,169.0 30.58 PACKER - PATCH - UPR Set Upper PIIP Patch Assembly (includes Packer, spacer pipe, anchor latch) OAL = 36.47' TTS CPP3 5309 7/18/2023 1.625 10,770.5 6,172.2 30.41 ANCHOR LATCH ON SPACER PIPE Part of Upper Patch Assembly (connected to Upper Patch Packer) TTS CPAL 35056 7/18/2023 1.600 10,779.0 6,179.5 30.01 LEAK - TUBING TUBING LEAK IDENTIFIED ON READ LEAK POINT ACOUSTIC LOG RUN 2/14/23 2/14/2023 2.992 10,801.4 6,199.0 29.32 ANCHOR LATCH ON SPACER PIPE Mid patch, PBR & anchor latch (OAL 41.37') TTS CPPB R3501 1/CPA L3516 0 7/17/2023 1.600 10,830.0 6,224.0 28.78 LEAK - TUBING TUBING LEAK IDENTIFIED ON READ LEAK POINT ACOUSTIC LOG RUN 2/14/23 2/14/2023 2.992 10,841.6 6,234.2 28.56 PACKER - PATCH - LWR Set lower P2P packer. TTS CPP3 5356 7/16/2023 1.620 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,374.0 11,394.0 6,718.6 6,737.2 A-4, A-3, 3K-26 7/23/1997 4.0 IPERF 2 1/8" Enerjet 90 deg. phasing; Oriented (+/-) 45 deg. FLSH 11,408.0 11,428.0 6,750.2 6,768.9 A-2, 3K-26 7/22/1997 4.0 IPERF 2 1/8" Enerjet, 90 deg. phasing 3K-26, 7/31/2023 4:42:44 PM Vertical schematic (actual) PRODUCTION 5.5x4.5"@11291'; 40.1-11,677.0 IPERF; 11,408.0-11,428.0 IPERF; 11,374.0-11,394.0 NIPPLE; 11,262.2 PACKER - PATCH - LWR; 10,841.5 LEAK - TUBING; 10,830.0 ANCHOR LATCH ON SPACER PIPE; 10,801.4 ANCHOR LATCH ON SPACER PIPE; 10,770.5 LEAK - TUBING; 10,779.0 PACKER - PATCH - UPR; 10,766.8 SURFACE; 41.1-6,779.1 NIPPLE; 499.5 CONDUCTOR; 43.0-122.0 KUP INJ KB-Grd (ft) 41.02 RR Date 7/22/1997 Other Elev 3K-26 ... TD Act Btm (ftKB) 11,690.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292276400 Wellbore Status INJ Max Angle & MD Incl (°) 72.06 MD (ftKB) 8,848.75 WELLNAME WELLBORE3K-26 Annotation Last WO: End DateH2S (ppm) 90 Date 11/1/2014 Comment SSSV: NIPPLE 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing patch 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: KRU Kuparuk River Oil Kuparuk River Oil 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11690 7013 11611 6939 11262 none Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email: Contact Phone: 907-265-6471 Authorized Title: Well Integrity Specialist Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11408 - 11394 11229 6750 - 6737 3.5 4.5 16 7.625 80 6738 Perforation Depth MD (ft): MD 122 4100 122 6779 700111677 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025519 197-077 P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22764-00 ConocoPhillip Alaska, Inc KRU 3K-26 Tubing Grade:Tubing MD (ft): 11269 MD / 6621 TVD No SSSV Perforation Depth TVD (ft):Tubing Size: L-80 11270 6/1/2023 Baker locator seal assembly No SSSV 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 and Digital Signature with Date: AOGCC USE ONLY Jan.Byrne@conocophillip.com m n P 1 6 5 6 t h Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:42 pm, May 17, 2023 323-292 Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2023.05.17 13:32:08-08'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne SFD 5/23/2023VTL 6/12/2023 DSR-5/17/23 10-404 X X -00 GCW 06/12/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.12 16:13:45 -08'00' RBDMS JSB 061423 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 17, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3K-26 (PTD 197-077) to install a retrievable tubing patch over known tubing leaks. Please contact me at 265-6471 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@ conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2023.05.17 13:31:20-08'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne Well Work JusƟĮcaƟon & ObjecƟves (and date required if appropriate): 3K-26 is a LTSI well, shut in since 2013. It is now being requested to get BOI for producƟon beneĮt in oīset producers. An acousƟc LDL located two tubing leaks 10,779' & 10,830'. This WWR is to patch over the tubing leaks. Risks/Job Concerns (Include DriŌ informa Ɵon on high deviaƟon wells, or wells with tag issues): • CA-2 plug at 11,262'. • Passed MITT and CMIT TxIA, but Failed MITIA with 0.46 GPM at 3000 psi • AcousƟc LDL located tubing leaks at 10,830' & 10779. • Need jumper line to take returns oī tubing to producƟon line • Need approved 10-403 from AOGCC prior to patch install. Steps(Author: please include SSSV notes and note any future work required to capture rate bene Įt listed above (include esƟmated days/units in cost)): Relay or Slickline/Eline 1. Pull CA-2 plug from 11,262'. 2. Brush and Ňush tubing string and driŌ for dummy patch to 10,850' (2.72" OD x 78' OAL, run in 3 secƟons ~4', ~40', ~34'). 3. Open Baker CMU sliding sleeve at 11,221'. 4. Pump 135 bbls (1.25x) seawater with 57 gallons of CRW-132 followed by 25 bbls diesel down IA. 5. Close Baker CMU sliding sleeve at 11,221'. 6. Set posiƟve pressure plug in CMU sliding sleeve proĮle at 11,221'. 7. Perform CMIT TxIA to 2500 psi to prove sleeve is holding. 8. Pull posiƟve pressure plug plug from sliding sleeve proĮle at 11,221'. 9. RIH with lower P2P and set mid element at 10,844'. Correlate to 2/14/23 READ LDL. 10. SƟng into lower P2P with test tool and perform CMIT TxIA to 3000 psi. Record TIOs. May need to pressure from IA side or jumper TxIA. Pull test tool. 11. RIH with spacer pipe and sƟng into anchor latch. Spacer pipe should be ~40' long. 12. SƟng into spacer pipe PBR with test tool and perform CMIT TxIA to 3000 psi. Record TIOs.May need to pressure from IA side or jumper TxIA. Pull test tool. 13. RIH with upper patch assembly and sƟng into spacer pipe PBR. The patch should be 74' element to element seƫng the upper P2P mid element at 10,070'. 14. Perform MITIA to 3000 psi. Record TIOs. 15. RDMO, turn well over to DSO. 16. DHD to perform SW MITIA once well is online and stabilized. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 11,489.0 3K-26 12/11/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: 2 Tubing leaks added - identified on acoustic LDL run 2/14/23 3K-26 2/14/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: CONDUCTOR EXTENDED 14"TO STABLIZE WELLHEAD 6/19/2016 pproven NOTE: View Schematic w/ Alaska Schematic9.0 11/3/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 43.0 122.0 122.0 62.58 H-40 WELDED SURFACE 7 5/8 6.88 41.1 6,779.1 4,100.4 29.70 L-80 BTC PRODUCTION 5.5x4.5"@11291' 5 1/2 4.95 40.1 11,677.0 7,001.2 15.50 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.2 Set Depth … 11,270.3 Set Depth … 6,622.1 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.2 36.2 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 499.5 499.5 0.75 NIPPLE 4.540 CAMCO DS NIPPLE 2.812 11,220.8 6,576.2 22.17 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE (Closed 08/10/21) 2.812 11,262.2 6,614.6 21.72 NIPPLE 4.540 CAMCO D NIPPLE 2.750 11,269.4 6,621.3 21.71 SEAL ASSY 4.000 BAKER LOCATOR SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,779.0 6,179.5 30.01 LEAK - TUBING TUBING LEAK IDENTIFIED ON READ LEAK POINT ACOUSTIC LOG RUN 2/14/23 2/14/2023 2.992 10,830.0 6,224.0 28.78 LEAK - TUBING TUBING LEAK IDENTIFIED ON READ LEAK POINT ACOUSTIC LOG RUN 2/14/23 2/14/2023 2.992 11,262.0 6,614.5 21.72 TUBING PLUG 2.75" CA-2 PLUG 12/14/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,374.0 11,394.0 6,718.6 6,737.2 A-4, A-3, 3K-26 7/23/1997 4.0 IPERF 2 1/8" Enerjet 90 deg. phasing; Oriented (+/-) 45 deg. FLSH 11,408.0 11,428.0 6,750.2 6,768.9 A-2, 3K-26 7/22/1997 4.0 IPERF 2 1/8" Enerjet, 90 deg. phasing 3K-26, 2/15/2023 4:57:53 AM Vertical schematic (actual) PRODUCTION 5.5x4.5"@11291'; 40.1-11,677.0 FLOAT SHOE; 11,675.6- 11,677.0 IPERF; 11,408.0-11,428.0 IPERF; 11,374.0-11,394.0 SBE; 11,270.6-11,291.1 SEAL ASSY; 11,269.4 TUBING PLUG; 11,262.0 NIPPLE; 11,262.2 SLEEVE; 11,220.8 LEAK - TUBING; 10,830.0 LEAK - TUBING; 10,779.0 SURFACE; 41.1-6,779.1 FLOAT SHOE; 6,777.6-6,779.1 LANDING COLLAR; 6,645.5- 6,646.8 CEMENTER; 1,890.2-1,892.6 NIPPLE; 499.5 CONDUCTOR; 43.0-122.0 HANGER; 41.1-42.7 HANGER; 36.2 KUP INJ KB-Grd (ft) 41.02 RR Date 7/22/1997 Other Elev… 3K-26 ... TD Act Btm (ftKB) 11,690.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292276400 Wellbore Status INJ Max Angle & MD Incl (°) 72.06 MD (ftKB) 8,848.75 WELLNAME WELLBORE3K-26 Annotation Last WO: End DateH2S (ppm) 90 Date 11/1/2014 Comment SSSV: NIPPLE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-14_22526_KRU_3K-26_LeakPointSurvey_Ttransmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 22526 KRU 3K-26 50-029-22764-00 LeakPoint Survey 14-Feb-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 Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophiIli ps.com> Sent: Monday, May 24, 2021 9:44 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: KRU 3K-26 (PTD 197-077) Report of failed CMIT TAA Attachments: 3K-26 90 day TIO 5.24.21.pdf, 3K-26.pdf Chris, KRU 3K-26 (PTD 197-077) is a secured LTSI well, shut in since 12/26/2013. While performing 3K pad state witnessed MITIA's this weekend 3K-26 failed a non -witnessed CMIT TxIA. Based on the pressure loss during the test it is believed that the plug has failed. Diagnostics with DHD and Slickline will be performed to locate and repair the source of communication. Follow up correspondence will be made after completion of the diagnostics and a plan forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 • \431 - 0/ 7 • ✓ . . ConocoPhiIIips RECEIVED Alaska JUL 0 1 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 /40GC June 29, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 cAMED DEC 92.01C Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name,top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincere of 1 jif Roger Winter ConocoPhillips Well Integrity Field Supervisor • • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 6/29/2016 3H&3K Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor! Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3H-31 50103202050000 1940190 12" NA 12" NA 3 6/22/2016 3K-25 50029228810000 1980810 10" NA 10" NA 5 6/22/2016 3K-26 50029227640000 1970770 14" NA 14" NA 12 6/22/2016 STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COM ION ' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate Alter Casin p r 9 F.7 Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Conductor Extension p- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 197-0770 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50-029-22764-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 KRU 3K-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11690 feet Plugs(measured) none true vertical 7013 feet Junk(measured) none Effective Depth measured 11611 feet Packer(measured) 11269 true vertical 6939 feet (true vertical) 6621 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 122' 122' SURFACE 6738' 7 5/8 6779' 4100' Production 11229' 51/2 11270' 6621' Liner 407' 41/2 11677' 7001' RECEIVED Perforation depth: Measured depth: 11408-11428', 11374-11394 JB 2016 True Vertical Depth: 6750-6769,6718-6737 SCANNEL JAN 2 5 28 - 1 , C C Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 11269 MD,6621 TVD Packers&SSSV(type,MD,and TVD) No SSSV SEAL ASSY= BAKER LOCATOR SEAL ASSEMBLY @ 11269 MD and 6621 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations P Exploratory r Development r Service F7 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-297 Contact MJ Loveland Email: n1878conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature Phone:659-7043 Date // ,did /77., 6/2d//b V/L9! /2. / (' Form 10-404 Revised 5/2015 RBDMS (A' JUN 2 3 2016 Submit Original Only • • Iry ConocoPhillips Alaska RECEIE P.O. BOX 100360 JUN 2 3 2016 ANCHORAGE,ALASKA 99510-0360 ,A:OGCC''' �► June 20, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3K-26,PTD 197-077 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ oveland ConocoPhillips Well Integrity Projects Supervisor • 3K-26 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/19/16 Welded a 10" Conductor Extension to stablize the well head 'V OF Tits • • gw\� Iyyy,�� THE STATE Alaska Oil and Gas of e T eSKTA Conservation Commission __ ALA 333 West Seventh Avenue troy"' Anchorage, Alaska 99501-3572 ,� R., GOVERNOR BILL WALKER g ��„ Main: 907.279.1433 F SSP Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland NSK Well Integrity Project Supervisor WANED SEP 2 2016 Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-26 Permit to Drill Number: 197-077 Sundry Number: 316-297 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this Zday of June, 2016. RBDMS \-'`'JUN 0 6 2016 RECEIVED • • • STATE OF ALASKA MAY 3 1 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION DT S 4 1 2 )b APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r" Fracture Stimulate r" Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r" Perforate New Pool f Re-enter Susp Well r Alter Casing P , Other Conductor Extension P. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development r- 197-0770 ' 3.Address: 6.API Number: Stratigraphic r' Service P. O. Box 100360, Anchorage, Alaska 99510 50-029-22764-00 ' 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?_NA I Will planned perforations require spacing exception? Yes r" No r ( KRU 3K-26 ' 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0025519' Kuparuk River Field/Kuparuk River 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): 11690 ., 7013 11611' • 6939' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 121' 121' SURFACE 6738' 7 5/8 6779' 4100' Production 11229' 51/2 11270' 6621' Liner 407' 4 1/2 11677' 7001' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11408-11428', 11374-11394 - 6750-6769,6718-6737 3 1/2 L-80 11269 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Camco'DS' Nipple-No SSSV ' MD=499 TVD=499 SEAL ASSY=BAKER LOCATOR SEAL ASSEMBLY ' MD=11269 TVD=6621 12.Attachments: Proposal Summary (V WellBore Schematic ✓ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch f Exploratory r Stratigraphic r Development r Service )74 14.Estimated Date for 15, Well Status after proposed work: 06/16/16 OILWIND Suspended Commencing Operations: r WDSPL r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r" Op Shutdown r- Abandoned r 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact. MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: n1878conocophillips.com Title: NSK Well Integrity Project Supervisor Signature _ i' ' �= Date: "'.-_-__,,,2 ,I Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: S \4 --.2- 1 2 Rug Integrity r- BOP Test r" Mechanical Integrity Test r- Location Clearance r- Other: RBDMS 1,1/ JUN 0 6 2016 Post Initial Injection MIT Req'd? Yes r No Spacing Exception Required? Yes r No rVf Subsequent Form Required: /'L, - 4 L Z.-- APPROVED BY Approved by: /' '94.44„...7 r—r ' aaz T 6/)//e 0 D 1 r.‘„, 1 COMMISSIONER THE COMMISSION 4Date:6) — 2...-- (i,..�r Gil/lc Form and r v Form 10-403 Revised 11/2015 p dddb c ti s for 12 months from the date of 1�pproval. Attachments in Duplicate • SRECEIVED MAY 312016 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 27, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3K-26, PTD 197-077 conductor extension. J Please contact me at 659-7043 if you have any questions. Sincerely, /? Gl�r MJ Love and ConocoPhillips Well Integrity Projects Supervisor . • • ConocoPhillips Alaska,Inc. Kuparuk Well 3K-26 (PTD 197-077) SUNDRY NOTICE 10-403 APPROVAL REQUEST 05-27-16 This application for Sundry approval for Kuparuk well 3K-26 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 10". With approval,the conductor extension will require the following general steps: 1. Examine surface casing for any corrosion damage if it is exposed. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP INJ 3K-26 ConocoP'hillips ® Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore States nut(°) MD(kKB) Act Ulm(kKB) ' cmorowylnpc 500292276400 KUPARUK RIVER UNIT INJ 72.06 8,848.75 11,690.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3K-26,1/11/2016 2'.50;35 PM SSSV:NIPPLE 90 11/1/2014 Last WO: 41.02 7/22/1997 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 11,487.0 12/8/2013 Rev Reason:PULLED CA-2 PLUG pproven 1/11/2016 .............................. HANGER:36.2 It Casing Strings. a,, i .^,7 L^ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(L..Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 41.1 6,779.1 4,100.4 29.70 L-80 BTC Casing DeseTption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' PRODUCTION 5 1/2 4.950 40.1 11,677 0 7,001 2 15.50 L-80 LTC MOD it Ili 55x4.5"@11291' ,. Tubing Strings Tubing De ription String Ma. ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 36.2 11,270.3 6,622.1 9.30 L-80 ABM-EUE Completion Details :. ✓--. Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 36.2 36.2 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 I 499.5 499.5 0.75 NIPPLE CAMCO DS NIPPLE 2.812 CONDUCTOR;42.0-121.0 i 1 _1,220.8 6,576.2 22.17 SLEEVE BAKER CMU SLIDING SLEEVE 2.812 11,262.2 6,614.6 21.72 NIPPLE CAMCO D NIPPLE 2.750 II11,269.4 6,621.3 21.71 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 NIPPLE;499.5 rePerforations&Slots <1 ;y. I Shot Dens Top(TVD) Bim(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,374.0 11,394.0 6,718.6 6,737.2 A-4,A-3,3K- 7/23/1997 4.0 IPERF 2 1/8"Eneryet 90 deg. 26 phasing;Oriented(+/-) 45 deg.FLSH '11408.0 11,428.0 6,750.2 6,768.9 A-2,3K-26 7/22/1997 4.0 IPERF 2 1/8"Enetiet,90 deg. y u „y phasing Notes:General&Safety End Date Annotation 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;41.1-6,779.1-1 SLEEVE;11,220.8 NIPPLE;11,262.2 I SEAL ASSY;11,269.4 irk: (PERF;11,374.0-11,394.0 IPERF;11,408.0-11,428.0 PRODUCTION 5.504.56511291%40.1-11,677.0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recia alaska.cov; AOGCC.Inspectors @alaska.00v; phoebe.brooks @alaska.gov chris.wallace @alaska.00v OPERATOR: ConocoPhillips Alaska,Inc I FIELD/UNIT/PAD: Kuparuk/KRU/3K Pad elf 6I It I t 3 DATE: 05/28/13 `7 7,17 OPERATOR REP: Hight/Phillips ! 9! .}_ AOGCC REP: 3 it 'r " Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-25 Type Inj. N TVD 6,765' Tubing 50 50 50 50 Interval 4 P.T.D. 1980810 Type test P Test psi 1691.25 Casing 170 3,027 2,975 2,960 P/F P Notes: Non witnessed OA 320 680 660 660 Well 3K-26 Type Inj. N " TVD "6,637' Tubing 2,300. 2,350 2,300 2,300" Interval 4 P.T.D. 1970770 ' Type test P Test psi "1659.25,Casing 770 3,025 2,981 "2,975 P/F P '..---- Notes: Non witnessed OA 560 710' 700 ' 700 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test SCAW4ED FEB 2 ®2014 Form 10-426(Revised 11/2012) 2013-0528 MIT KRU 3K-pad 2wells.xlsx • MEMORANDUM TO: Jim Regg ~~~~ ~ /I P.I. Supervisor 6 FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-26 KUPARUK RIV UNIT 3K-26 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~'z-- Comm Well Name: KUPARUK RIV UNIT 3K-26 Insp Num: mitCS090515164934 Rel Insp Num: API Well Number: 50-029-22764-00-00 Permit Number: 197-077-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-26 Type Inj. W TVD 6637 IA 800 2300 2300 2300 P.T.D 1970770 TypeT6St ~ SPT Test psi 1659.25 OA 600 600 600 600 Interval 4YRTST p~ P ~ Tubing 2050 2050 2050 2050 Notes: Pretest pressures observed and found stable . Well demonstrated good mechanical integrity. i '-~ -: Wednesday, May 20, 2009 Page 1 of 1 . . Conocó'Phillips Alaska ,JUL 0 3 2007 & Gas Cons, Commission P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 \CA.1/011 sCANNED JUL 05 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips W ell Integrity Supervisor . . Co no co Phillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na gal 1C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1C-133 201-077 16" none 16" na 8.5 7/1/2007 1C-190 203-003 27" none 27" ~- 11I10 6/24/2007 ~ _'ii,,' libll}" II 6/24/2007 186-165 6" none 6" na 3 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 (j ~-~ ...... ~~~~_._---- " .~,----= '" 01/02/07 Schlullberger . ___C.-··· NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 SCANN~D JAN 0 ß 2007 U· .--. Œ .-1.. I g '7-- tSr1- Field: Kuparuk ...'''''... ,"'~... ' BL Color CD Well Log Description Date Job # 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 10-109 N/A INJECTION PROFILE 11/27/06 1 1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A SBHP/DD 12/18/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 10-103 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 3S-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . n' .1.£,,1 V. U.Kf\.l".lJ U lVl ) Jim Regg. 'K~H A { ! 4-(' ò~ç P.I. Supervisor ( r ~nate 01 Alaska '\ Alaska Oil and Gas Conservation Commb~..Jh FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, May 25,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-26 KUPARUK RIV UNIT 3K-26 \C\1·011 TO: Src: Inspector Reviewed By: P.I. SuprV\ ~t:..- Comm Well Name: KUPARUK RlV UNIT 3K-26 Insp Num: mitCS050521155900 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-22764-00-00 Permit Number: 197-077-0 Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-26 [Type Inj. w I TVD 6656 IA 960 2180 2160 2160 P.T. 1970770 ITypeTest SPT Test psi 1664 OA 720 780 780 780 Interval 4YRTST P/F P Tubing I 2750 2750 2750 2750 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCAi'U\tED JUL {} 7 2005 Wednesday, May 25, 2005 Page I of I ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test C\'\"" 01'1 Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. £CANNEO MAY 2 6; 2005 ~ ,I FIELD I UNIT I PAD: Kuparuk I KRU/ 3K DATE: 05/21 105 OPERATOR REP: Arend I Sauvageau - AES AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. well3K-02 I Type Inj I S I T.V.D. 6421 I Tub~ng I 27501 27501 27501 27501 Interval r 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 I 550 I 550 I 550 well3K-04 I Type Inj I S I T.V.D. 6431 I Tub~ng I 30001 30001 3000f 30001 Interval \ 4 P.T.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 I 350 I 350 I 350 Well3K-05 I Type Inj I S I T.V.D. 6341 I Tubing I 27501 27501 27501 275Ollnterval 4 P.T.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 I 940 I 940 I 940 Well\3K-07 I Type Inj I S I T.V.D. 6565 I Tubing I 29501 29501 29501 2950 \ Interval I 4 P.T.D. 1861250 Type Test P Test psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 I 340 I 340 / 340 we1l13K-12 I Type Inj I S 1 TV.D. 6644 I Tubing I 28501 28501 28501 285Ollnterval 0 P.T.D. 1861650 Type Test P Test psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 I 480 / 480 I 480 well3K-13 I Type Inj I S I T.V.D. 6376 I Tubing I 28501 28501 28501 2850 Intervall 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 I 600 I 600 / 600 Well\3K-15 1 Type Inj I S I Tv.D·1 6448 I Tubing I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 I 450 / 450 / 450 well3K-18 1 Type Inj I S I Tv.D·1 6605 I Tubing I 22001 22001 22001 2200 Interval I 4 P.T.D. 1861510 Type Test P Test psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 I 560 I 560 I 560 well3K-19 I Type Inj I S I T.v.D. I 6331 I Tub~ng I 27501 27501 27501 2750 Intervall 4 P.T.D. 2011080 Type Test P Test psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 I 620 I 620 I 620 well3K-25 1 Type Inj 1 N I T.V.D. 6552 I Tub~ng 1 27~1 2751 2751 2751lnterval 4 P.T.D. 1980810 Type Test P Test psi 1638 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 / 600 / 600 Well\3K-26 \ Type Inj I S I T.V.D.\ 6656 I Tubing 1 27501 27501 27501 2750 \ Interval I 4 P.T.D. 1970770 Type Test P T est psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 720 I 780 I 780 I 780 Well\3K-30 1 Type Inj 1 S I T.V.D·I 6580 I Tubing I 28501 28501 28501 2850 1 Interval I 4 P.T.D. 1971130 Type Test P Test psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 I 460 I 450 I 450 well3K-31 I Type Inj I S I T.V.D. 6117 I Tub~ng I 285~1 28501 28501 28501 Interval \ 4 P.T.D. 1980820 Type Test P Test psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 I 600 I 600 well3K-34 I Type Inj I S I T.V.D.\ 6285 I Tub~ng 1 28501 28501 28501 2850 \ Interval \ 4 P.T.D. 1980770 Type Test P Test psi 1571 Casing 300 2140 2140 2140 P/F P Notes: OA: 400 I 650 I 650 I 650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M :: Annulus Monitoring I = Initial Test G = Gas Inj P :: Standard Pressure Test 4 :: Four Year Cycle S = Salt Water Inj R :: Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A:: Temperature Anomaly Survey Test during Workover D:: Differential Temperature Test 0= Other (describe In notes) MIT Report Form MIT KRU 3K 05-21-05.xls 5/24/2005 Revised: 05/19/02 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 27, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ~OMM ~ /~ 60~i'~ ~ ~o1~ iRES ENG _ SR ENG NRO SR GE. OL, GEOL ASST ST^f ~ECH ~ STAT T~CH~ ~ ,., Subject: 3K-26 Dear Mr. Commissioner: Enclosed please find a LOT plot, cementing detail and the casing detail sheets for Kuparuk Well 3K-26. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad cc: Blair Wondzell SCANNED OCT 04 MAY 29 ~ & Gas Cons. CASING AND LEAK-OFF FRACTUR .E. TESTS Well Name: Supervisor: KRU 3K-26 Date: 5/25/97 Donald Lutrick 7 5/8", 29.7#, L-80, BTC Casing Size and Description: Casing Setting Depth: Mud Weight: 8.4 6779' TMD 4101' TVD ppg EMW -- Leak-off Pressure (PLO) + MW 0.052 x TVD LOT = 885 psi/(0.052 x 4101 ft) + 8.4 ppg = 12.55 ppg Fluid Pumped = 1.36 bbls. Hole Depth (md)= 6338' Pump output = .085 bps 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 80O 700 600 500 40O 300 200 100 0 ,. ~_...]mB U mm ~ m mJUU , , J l + LEAK-OFF TEST "' ~ ~ ~ CASING TEST i iii i i ii 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 6.0 STROKES D SCANNED OCT 0 & 2002 t~A'f ?_.9 1997 R!as~ Cji & Gas ,Cons. ARCO Alaska, Inc. Cementing Details Well#: Casing Size 7 5/8" Centralizers Mud Spacer Lead Cement STAG E 1/2 Tail Cement STAG E 1/2 Displacement 3K-26 Hole Diameter 9.875" Field: KUPARUK Hole Angle Shoe Depth 65° 6,789' Date: Float Depth 6,645' 3/23/97 % washout State type used, intervals covered and spacing 39 Gemco centralizers. Jts # 1 - 37 and on either side of ES cementer Weight 9.9/9.7 Gels before 4/13 JYP(Prior cond) 16 lbs/100 ft2 2/~5~ls after Type Water Type I Mix wtr temp ASLW I 7 0 Additives YP(after cond) ]PV(prior cond) 13 lbs/lO0 ft21 26 cP Total Volume Circulated 600 bbls Volume 50/20 No. of sacks 200/222 Weight 10.5/10.5 PV(after cond) 20 cP Weight 8.3 PPG Yield 4.41 G + 3.5% DO44, .6% DO46, 30% D53, 1.5% DO79, 50% D124, 1.5% SOO1 G/AS I 70 600/50 15.8/15.8 1.15/0.93 STAGE 1: G , 2.66% DO29, .2% DO46, .3% DO65, 1.5% SOO1 STAG E 2: AS I Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 9 9 225 Reciprocation speed 10 fpm Actual Displacement 3O5/87 Bumped plug Floats held yes/yes yes/yes Reciprocation length 10 Theoretical Displacement STAGE 1/2 305/87 Calculated top of cement I CIP 5/23/97 1762'/surface 1°6:33/08:16 Str. Wt. Dn. 125 Str. Wt. Mud Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage 1: Reciprocated csg until cement rounded shoe. Had full returns through out job Stage 2: Opened ES cementer w/3350 psi. Circ out cement contaminated mud. Had cement to surface w/ 175 bbls cement pumped. Switched to tail. Displaced w/ rig pumps. Closed cementer w/2000 psi. Floats OK Had 100% returns throughout entire job. Cement Company I Rig Contractor Dowell I Parker ISignature Donald Lutrick SCANNED OCT 0 4 2002 1997 ns. r~ndiO-~l~'~~ CASING / TUBING / LINER DETAIL ARCO ALASKA / Subsidiary of Atlantic Richfield WELL: 3K-26 DATE: 5/23/97 PAGE: 1 of I # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH , 7 5/8" SURFACE CASING TOPS Above RKB -4.55 Landing Joint 45.55 -4.55 ,,, 7 5/8", 29.7#, L-80 Fluted mandrel hanger 1.51 41.00 42 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 1804.05 42.51 B' Jt 7 5/8", 29,7#, L-80, BTC, R-3, Class A-BakerLocked 43.68 1846.56 , Halliburton ES Cementer 2.39 1890.24 A' Jt 7 5/8", 29.7#, L-80, BTC, R-3, Class A-BakerLocked 43.75 1892.63 110 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 4709.09 1936.38 , ,,, ,, Halliburton Landing Collar 1.37 6645.47 1 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 42.86 6646.84 Gemoco 7 5/8" Float Collar 1.33 6689.70 2 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 86.54 6691.03 Gemoco 7 5/8" Float Shoe 1.49 6777.57 Shoe set @ 6779.06 ES Cementer and lock Jts (A & B)between jt #113 - #114 TD -- 6789.00 PBTD-- 6645.47 RATHOLE = 9.94 I Parker 245 RKB to Wellhead = 41.08 FLUTED HANGER GOES IN TOP OF JT. #155 **9 Jts (#156 -~164) stay in the shed **. BAKER-LOCK TO TOP OF BAFFLE COLLAR JT. National lead free mod. (BOL 2000) TORQUED TO BASE OF TRIANGLE (avg 9000 R-Lbs) , , ,, RAN: 37 bow spring centralizers on jt #1 thru #37 D~i~'~ ~ i ''~ D 2 bowspring centralizers on jt #A and #B 1997 RIG SUPERVISOR: Donald Lutrick SCANNED OCT 0 A 2002: O1'4 OR BEFORE ANuARY 03 200[ C:-LOP,1XMI: ILM.DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 97-077 MWD SRVY 97-077 DGR/EWR4-MD 97-077 DGR/EWR4-TVD 97-077 8076 97-077 BH PR~S-TEMP 97-077 CMT MAP 97-077 INJP-SPIN/TEM/ ~0.-11690. ~4~1_5_7013 ~/~-PERRY MPT/GR/EWR4/ROP L 11300-11428 ~F~1150-11566 J RES 11300-11500 10-407 DAILY WELL OPS ~'~OMPLETION DATE R @ ?/Iq £3?/ TO Are dry ditch samples required? yes ~And received? Was the well cored? yes ~..~Analysis & description received? Are well tests required? /yes ~_~eceived? yes no ~: Well is in compliance In'itial COMMENTS Page: 1 Date: 07/19/99 RUN RECVD 06/11/97 FINAL 08/20/97 FINAL 08/20/97 5 08/20/97 FINAL 09/29/97 FINAL 10/15/97 FINAL 01/05/99 T D BOX -- ARCO Alaska, Inc. Post Office Box , o0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note #1 below25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1C-15 16695 100 0 16795 0 16795 2L-313 8554 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously re ~orted volume of 220 barrels was pumped into this annulus during the drilling of the well. This was the volume required roi'lush and freeze protect the annulus during initial drilling operations, not a volume of disposal fluids injected prior to the receipt of authorization .for annular injection. Total Volumes into Annuli for which Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1C-12 34995 100 0 35095 Open, Freeze Protected 1C-13 26800 100 0 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO' s, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company AFI3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two I Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume Volume ! Injected Annulus 2A-22 16749 100 0 [ 16849 Open, Freeze Protected 2F-19 20725 100 0 20825 Open, Freeze Protected 3K-27 37173 100 0 37273 Open, Freeze Protected 3K-26 33970 100 0 34070 Open. Freeze Protected 1E-31 33645 100 0 I 33745 Open, Freeze Protected 1E-32 45205 100 0 45305 Open, Freeze Protected 3Q-22 6245 100 0 6345 Open, Freeze Protected 1Q-24 23158 100 0 t 23258 Open, Freeze Protected 1Q-26 25931 1 oo 0 [ 26031 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files 12/21/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12181 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia ID-110 CBL-SCMT 981020 1 1 2L-329A CBL-SCMT 981122 1 1 2L-329A PRODUCTION LOG 98i205 1 1 2L-329A PRODUCTION LOG 981207 1 1 2N-321A CBL-SCMT 981109 1 1 2N-325 CBL-SCMT 981108 1 1 2N-325 MI INJECTION PROFILE 981205 1 1 2N-331 CBL-SCMT 981123 1 1 IE-35 CEMENT MAPPING LOG 981203 1 1 1 E-35 PRODUCTION LOG 981208 1 1 1 E-36 STATIC PRESS/TEMP 981123 1 1 IG-16 LAde. _ MI INJECTION PROFILE 981202 1 1 1Q-07 STATIC PRESS/TEMP 981119 1 1 1Y-15A CBL-SCMT 981109 1 1 2M-34 I.k~c~ MI INJECTION PROFILE 981110 1 1 2W- 12 PRODUCTION PROFILE 981028 1 1 3F-04 ~lc.~ MI INJECTION PROFILE 981203 1 1 3F-12 I~,~ C... MI INJECTION PROFILE 981204 1 1 3F- 19 RST WFL & GLS 981103 1 1 3G-03 PROD PROFILE W/DEFT 981104 1 1 3K-25 ~{( ~ INJECTION PROFILE 981014 1 1 3K-26 ~.. ~. INJECTION PROFILE 981014 1 1 . ~ b , o"lq SIGNE DATE: ~1o~o ~i~n ~nd r cop ~ ~hi~ ~r~n~mi~l ~o Shorrio ~ ~ho ~ovo ~ddro~. lh~nk ~ou. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 6, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-26 (Permit No. 97-77) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-26. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad ORISINAL 1997 ;a, nch0rago STATE OF ALASKA ALASK . OIL AND GAS CONSERVATION C,.. AMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-77 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 5. 1272' FSL, 317' FWL, Sec 35, T13N, RSE, UM At top of productive interval 679' FSL, 2071' FEL, Sec. 36, T13N, R9E, UM At total depth 669' FSL, 1895' FEL, Sec. 36, T13N, RSE, UM .... Elevation in feet (indicate KB, DF, etc.) I6. Lease Designation and Serial No. Rig RKB 41', Pad 34' I ADL 25519, ALK 2555 8. APl Number 50-029-22764 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3K-26 11. Field and Pool Kuparuk River 12. Date Spudded i13. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 5/19/97 i 5/28/97 I 7/22/97 i N/A MSLI One 17. Total Depth (MD+TVD)! 18. Plug Back Depth (MD+TVD)i19. Directional Surveyl20. Depth where SSSV set[21. Thickness of Permafrost 11690' 7013' F-rI 11611 6939 F~ [~Yes I~No! N/A MD~ 1650' (Approx.) 22. Type Electric or Other Logs Run GR/Res, CCL/GR/SLTJ 23. CASING, LINER AND CEMENTING RECORD I'Hot_~ VVT. PER FT. GRADE SETTING DEPTH 151.5# X-65 29.7# L-80 15.5# L-80 12.75# L-80 CASING S~ZE 16" 17.625" 4.5" ToP Bo~I'OM Surf. 121' Surf. 6779' Surf. 11270' 11270' 11677' CEMENTING RECORD AMOUNT PULLED 129 SX AS I 422 sx ASLW, 600 sx class 'G', 50 sx AS 220 sx Class 'G' tapered string 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11 286' F ~ ¢~, m i26. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED CHOKE SIZE GAS-OIL RATIO CiE G~Avr~LAPI (CORR) WATER-DEL WATER-BBL I_ 6.75"____ 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) ¸27. MD TVD MD TVD 11408'-11428' 6750'-6769' 4 spf 11374'-11394' 6718'-6737' 4 spf Date First Pr0duc(i°n Date of Test iHours Tested PRODUCTION TEST 'Method Of Operation' (Fl~'wing, gas lift, etc.) ~ Water Injection PR~)-~~O-~-L~B L GAS-MCF TEST PERIOD · ~ALCUI~.TF~)---¥- I (~ii~--B~_ GAS-MCF 24-HOUR RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit o ~ll~' ~ ~ ¢'=~ ij .~'~ Flow TubingiCasing Pressure Press. 28. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marl,¢ -' 30 Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered i Depth Depth and gravity, GOR, and time of each phase. Marker Name Top Kuparuk C 11205' 6562' Total pump volumes for this event: Bottom Kuparuk C 11255' 6608' Category 1. 9220 Top Kuparuk A 11363' 6708' Category 2. 100 Bottom Kuparuk A 11493' 6829' Category 3. 0 Total: 9860 Total To Date: 9320 Annulus left open - freeze protected with diesel. "3"i'J Li~¥'of A~tachments I I ........ Summary of Daily Drilling Reports, Surveys 32. I hereby certify th~ foregoing is true and correct to the best of my knowledge Signed ~ Title ~:'1[,'~-~_ ~~ Date ,=A~(& / a, ~ Pre~aredLt~y Name/Number: 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 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5". Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 7/22/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3K-26 RIG'PARKER 245 WELL ID: AK8805 TYPE: AFC: AK8805 AFC EST/UL:$ 1340M/ 1610M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK' SPUD:05~19/97 START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22764-00 05/19/97 (D1) TD: 1464' (1464) SUPV'DCL DAILY:$ 05/20/97 (D2) TD: 4970' (3506) SUPV:DCL DAILY:$ 05/21/97 (DB) TD: 6333' (1363} SUPV:DCL DAILY:$ 05/22/97 (D4) TD: 6789' (456) SUPV:DCL DAILY:$ 05/23/97 (D5) TD: 6789' ( 0) SUPV:DCL DAILY:$ 05/24/97 (D6} TD: 6809' ( 20} SUPV:DCL DAILY'$ 05/25/97 (D7) TD' 9130' (2321) SUPV:DCL DAILY:$ 05/26/97 (D8) TD:10631' (1501} SUPV: DCL DAILY: $ MW: 9.1 riSC: 76 PV/YP: 23/27 APIWL: 6.4 DRILLING Move rig from 3K-32 to 3K-26. Accept rig @ 0630 hrs. 5/19/97. NU diverter system. Function test diverter. OK. Drill from 121' to 1464' 105,134 CUM:$ 105,134 ETD:$ 157,005 EFC:$ 1,288,129 MW: 9.1 riSC: 60 PV/YP' 19/20 DRILLING Drilling from 1464' to 4970' 86,747 CUM'$ 191,881 ETD:6 391,970 EFC'$ APIWL: 6.8 1,139,911 MW: 9.3 VISC: 56 PV/YP: 21/18 APIWL: 7.8 DRILLING Drilling from 4970' to 6333'. Finish circ lo/hi vis sweep. POH. Hole tight. Pump out from 4300' to 1835' 71,197 CUM:$ 263,078 ETD:$ 483,316 EFC:6 1,119,762 MW: 9.5 VISC: 48 PV/YP: 18/14 APIWL: 5.6 CEMENT 7-5/8" CASING Drilling from 6333' to 6789' Circ lo/hi vis sweep. No problems. Held prejob safety meeting. RIH w/7-5/8" casing. 72,952 CUM:$ 336,030 ETD:$ 516,542 EFC:$ 1,159,488 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CEMENT 7-5/8" CASING Finish RIH w/7-5/8" casing. Land casing at 6779'. Pump cement. NU BOPE. Test all BOPE to 300/3000 psi. 208,119 CUM:$ 544,149 ETD:$ 516,542 EFC:$ 1,367,607 MW: 8.4 VISC: 29 PV/¥P: 1/ 1 APIWL: 20.0 DRILLING Drill out cement and ES cementer. Tag cement at 6350' Drill out cement, float equipment and new formation to 6809' Performed LOT 12.55 EMW. 69,278 CUM:$ 613,427 ETD:$ 519,787 EFC:$ 1,433,640 MW: 8.9 VISC: 42 PV/YP: 13/12 APIWL: 6.4 WIPERTRIP Drilling from 6809' to 9130' -- 84,613 CUM'$ 698,040 ETD'$ 896,346 EFC:$ 1,141,694 MW' 10.1 VISC- 47 PV/YP: 18/18 APIWL: 5.2 WIPERTRIP Drilling from 9130' to 10631' .. ~ 88,906 CUM:$ 786,946 ETD'$ 1,139,869 EFC:$ 987,077 ~,~¢~ 7 1997 4/._a_s~.Oil .& [:;a.s Oons. Cornmis~: Ar~chomge Date: 7/22/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/27/97 (D9) TD:11448' (817) SUPV:DEB DAILY:$ MW: 10.2 VISC: 51 PV/YP: 18/20 APIWL: 4.4 SHORT TRIP FROM TD @ 11690' Drilling from 10631' to 10854'. Test formation to 13.6 ppg EMW. Drill to 11448' and drilling ahead. 84,408 CUM:$ 871,354 ETD:$ 1,272,419 EFC:$ 938,935 05/28/97 (D10) TD:l1690' (242) SUPV:DEB DAIL¥:$ MW: 10.2 VISC: 57 PV/YP: 22/26 APIWL: 4.3 RUNNING 5.5 X 4.5" CASING Drilling from 11448' to 11690' Circulate lo-hi vis sweeps around. Monitor well, static. Pump slug. 74,172 CUM:$ 945,526 ETD:$ 0 EFC:$ 2,285,526 05/29/97 (Dll) TD:l1690' ( 0) SUPV:DEB DAILY:$ MW: 10.2 rISC: 49 PV/YP: 16/22 APIWL: SET 5.5" CASING ON SLIPS Held prejob safety meeting on running casing. Run 4.5" casing. Run 5.5" casing. Start losing mud. Circulate. Continue to run 5.5" casing, very little returns. Run casing to 11675' Circulate casing, casing packed off. Worked 2 hfs to get returns back. Slowly increasing rate, with full returns. 167,145 CUM:$ 1,112,671 ETD:$ 0 EFC:$ 2,452,671 4.6 05/30/97 (D12) TD:l1690' ( 0} SUPV:DEB DAILY:$ MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RU TO FREEZE PROTECT TBG & ANN Pump cement. Bumped plug. Checked floats, OK. Had full returns throughout job. Install packoff. NU tubing head. Test packoff to 3000 psi for 15 minutes, OK. NU BOPs. Held prejob safety meeting on running tubing. Run 3.5" tubing. 99,441 CUM:$ 1,212,112 ETD:$ 0 EFC:$ 2,552,112 05/31/97 (D13) TD:l1690' ( 0) SUPV:DEB DAILY:$ MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Run 3.5" completion string. Test 5.5" x 4.5" casing to 3500 psi for 30 min, OK. Test tubing to 3500 psi, OK. Test annulus to 3500 psi, OK. ND BOPs. NU master valve. Release rig @ 1430 hrs. 5/31/97. 134,796 CUM:$ 1,346,908 ETD:$ 0 EFC:$ 2,686,908 End of WellSummary for Well:AK8805 KUPARUK RIVER UNIT WELL SERVICE REPORT KI(3K-26(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-26 PERFORATE, PERF SUPPORT 0620970508.1 DATE DAILY WORK UNIT NUMBER 07/22/97 CEMENT BOND LOG, 2 1/8" EJ PERFORATE 8293 DAY OPERATION COMPLETE I SUCCESSFUL ] KEYPERSON SUPERVISOR 3 NO YES SWS-JOHNSON JORDAN InitialTbgeress IFinalTbgPress [InitiallnnerAnn IFinallnnerAnn IlnitialOuterAnn I Final Outer Ann 0 PSI 600 PSI 0 PSI 0 PSI 550 PSI 550 PSI DAILY SUMMARY CEMENT GOOD OVER ENTIRE 4 1/2" LINERPERFORATED 11408' TO 11428' TIME LOG ENTRY 09:00 MIRU SWS UNIT 8293; ENG: JOHNSON 10:30 RIH WITH CENT/TEL CART/CENT/CMT/CENT MAX OD=- 1 11/16" 11:15 TAG TD AT 11577'BEGIN LOGGING REPEAT SECTION FROM 11566' TO 11300'LOG MAIN PASS FROM 1 i 566' TO 11150' 12:10 POOH 13:30 OUT OF HOLEPUT'IDGETHER LOG AND MAKE PRINTSSET UP PERI: EQUI? 16:00 PRESSURE TEST RISER/BOP TO 3000g 16:30 RIH WITH 6'Xl 11/16" WT/20' 2 1/8" ENERJET PERF GUN4 SPF, DP CItARGES, 90 DEG PASE 16:50 TIE INTO CMT DATED 7/22/97LOG TIE IN PASSPRESSURE TUBING UP TO 130On WITH TRIPLEX PUMP 17:30 PERFORATE 11408' TO 11428' 17:40 POOH 19:10 RDFN, SHOOT SECOND INTERVAL IN MORNING ARCO Alaska, Inc. A KUPARUK RIVER UNIT WELL SERVICE REPORT WELL JOB SCOPE 3K-26 PERFORATE, PERF SUPPORT DATE 07/23/97 DAY 4 DAILY WORK PERFORATE 'A' SAND/SIBHP OPERATION GOMPLI~-IE [ SUCCESSFUL YES I YES Initial Tbg Press [ Final Tbg Press {600 PSI 0 PSI DAILY SUMMARY Initial Inner Ann 0 PSI Kl(3K-26(W4-6)) JOB NUMBER 0620970508.1 UNIT NUMBER 8293 KEY PERSON SUPERVISOR SWS-JOHNSON JORDAN Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 550 PSII 0 PSI PERFED 11,374'-11,394', 2 1/8" EJ DP, 4 SPF, +/- 45 DEG FLSH.SIBHP AT 11,400'=3505 PSI. TEMP=162 DEG/F. I TIME LOG ENTRY 08:00 MIRU SWS 8293, JOHNSON. TGSM. PT LUB/BOP'S TO 3000g. 09:00 RIH W/GUN #1. CCL/MPD/20' X 2 1/8" El' DP (90 DEG. PHASED), 4 SPF. TIED INTO CMT 7/22/97. PERFED 11374'-11397' +/- 45 DEG LSH.POOH, ALL SHOTS FIRED. 12:3 0 RIH W/WTBAR/CCL-GR/PRESS/TEMP. LOG SBHP AT 11400'. INITIAL PRESS=3800 PSI. STBY TO STABALIZE WELL. 15:00 LOG PRESS/TEMP 30 MIN.,. FINAL PRESS=3505 PSI. TEMP=162 DEG/F. POOH 17:00 RDMO ARCO ALASKA, INC. KRU / 3K-26 500292276400 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -75.30 120.00 120.00 44.70 448.00 447.99 372.69 633.00 632.97 557.67 725.00 724.96 649.66 COURS INCLN DG MN -SUN DRILLING SERVICES ANCHORAGE ALASKA 0 0 0 0 0 45 0 45 1 15 834.26 834.06 758.76 4 49 925.35 924.56 849.26 8 3 1020.47 1018.19 942.89 12 16 1111.14 1106.27 1030.97 15 20 1203.16 1194.41 1119.11 18 0 1295.88 1281.72 1206.42 21 17 1389.95 1368.66 1293.36 23 32 1483.67 1453.75 1378.45 25 58 1574.88 1534.61 1459.31 29 7 1665.26 1612.44 1537.14 31 57 1755.14 1687.45 1612.15 1847.57 1762.00 1686.70 1940.49 1834.04 1758.74 2033.54 1902.84 1827.54 2126.30 1968.21 1892.91 34 53 37 34 40 45 43 52 46 30 7,0'7 PAGE DATE OF SURVEY: 052897 MWD SURVEY JOB NUMBER: AK-MM-70145 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC 2219.58 2032.71 1957.41 46 0 2312.60 2096.50 2021.20 47 22 2405.62 2158.39 2083.09 49 11 2498.71 2217.57 2142.27 51 50 2588.92 2271.89 2196.58 54 5 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2681.26 2323.97 2248.67 2774.10 2372.07 2296.77 2866.02 2415.87 2340.57 2958.21 2456.43 2381.13 3051.50 2495.91 2420.61 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 1.00 E .23 2.15N .04E N 26.00 E .18 4.45N .59E N 29.00 E .55 5.86N 1.34E .00 .00 -.14 .21 .84 N 88.51 E 3.96 7.03N 6.52E S 84.99 E 3.62 6.57N 16.71E S 69.42 E 5.26 2.43N 32.82E S 86.98 E 5.69 1.595 53.83E S 85.42 E 2.93 3.375 80.16E 5.90 16.10 32.50 53.77 80.16 S 84.36 E 3.58 6.175 lll.21E S 83.87 E 2.40 9.855 146.89E S 84.62 E 2.60 13.785 185.94E S 84.39 E 3.46 17.825 227.92E S 83.89 E 3.15 22.515 273.60E 111.33 147.20 186.44 228.61 274.52 3329.36 2609.05 2533.75 3605.44 2721.93 2646.63 3878.99 2844.07 2768.77 4157.07 2969.92 2894.62 4435.74 3090.02 3014.72 S 84.16 E 3.26 27.665 322.84E S 83.92 E 2.90 33.345 377.16E S 83.41 E 3.44 39.825 435.47E S 84.80 E 3.51 46.235 497.78E S 85.80 E 2.93 51.615 563.36E 324,02 378.63 437.28 499.90 565,70 S 85.64 E .54 56.645 630.56E S 85.49 E 1.48 61.875 698.04E S 83.80 E 2.37 68.375 767.16E S 83.12 E 2.91 76.565 838.53E S 84.03 E 2.62 84.615 910.08E 633.09 700,77 770,19 842.00 913.98 57 13 60 21 62 4'2 65 4 64 50 S 84.40 E 3.39 92.295 985.93E S 84.73 E 3.40 99.805 1064.97E S 85.35 E 2.62 106.785 1145.46E S 85.87 E 2.62 113.115 1227.98E S 84.93 E .95 119.895 1312.23E 990,20 1069.59 1150.38 1233.14 1317,67 67 4 64 39 62 17 63 54 65 2 S 85.93 E .87 140.095 1565.14E S 86.96 E .94 155.735 1816.57E S 86.95 E .86 168.735 2060.93E S 83.13 E 1.35 190.225 2307.92E S 84.99 E .73 216.225 2557.99E 1571.37 1823.24 2067.82 2315.74 2567.11 ORIGINAL f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA, INC. KRU / 3K-26 500292276400 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052897 MWD SURVEY JOB NUMBER: AK-MM-70145 KELLY BUSHING ELEV. = 75.30 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4710.38 3210.91 3135.61 4986.89 3337.21 3261.91 5265.71 3461.72 3386.42 5541.24 3580.01 3504.71 5818.03 3702.96 3627.66 62 43 62 54 64 2 65 6 62 8 S 86.88 E 1.04 233.74S 2803.93E S 85.98 E .30 249.06S 3049.42E S 85.09 E .50 268.49S 3298.12E S 84.57 E .42 290.91S 3545.94E S 85.36 E 1.10 312.70S 3792.92E 2813.66 3059.57 3309.01 3557.84 3805.79 6091.61 3821.80 3746.50 6254.08 3888.16 3812.86 6462.33 3971.85 3896.55 6711.33 4072.24 3996.94 6911.68 4153.09 4077.79 66 21 65 25 67 10 65 16 67 9 S 87.82 E 1.74 327.25S 4038.83E S 87.05 E .72 333.89S 4186.97E S 85.72 E 1.02 345.92S 4377.24E S 87.71 E 1.05 359.01S 4604.71E S 82.12 E 2.72 375.31S 4787.21E 4052.04 4200.22 4390.83 4618.59 4801.82 7187.76 4265.10 4189.80 7464.78 4384.72 4309.42 7834.13 4550.30 4475.00 8201.12 4721.13 4645.83 8479.64 4844.10 4768.80 65 0 63 49 62 54 61 35 65 59 S 87.59 E 1.97 398.03S 5038.41E S 87.50 E .43 408.73S 5288.03E S 87.17 E .26 424.08S 5617.81E S 87.06 E .36 440.42S 5942.18E S 85.16 E 1.69 457.45S 6191.41E 5054.04 5303.67 5633.58 5958.17 6207.95 8848.75 4976.19 4900.89 9035.12 5034.48 4959.18 9124.38 5066.65 4991.35 9215.78 5105.80 5030.50 9308.74 5149.96 5074.66 72 3 71 31 66 12 63 3 60 12 S 82.22 E 1.80 495.48S 6533.75E S 88.20 E 3.06 510.27S 6710.07E S 88.11 E 5.95 512.95S 6793.25E S 87.70 E 3.47 515.97S 6875.78E S 86.24 E 3.36 520.28S 6957.45E 6552.28 6729.22 6812.33 6894.81 6976.56 9401.63 5198.00 5122.70 9494.09 5248.74 5173.44 9587.25 5302.81 5227.51 9679.23 5359.67 5284.37 9768.71 5417.16 5341.86 57 30 55 55 53 6 50 30 49 32 S 86.82 E 2.97 525.09S 7036.80E S 87.57 E 1.83 528.88S 7113.99E S 88.81 E 3.22 531.29S 7189.80E S 87.90 E 2.93 533.35S 7262.06E S 85.95 E 1.99 537.02S 7330.52E 7056.03 7133.27 7209.02 7281.19 7349.72 9860.81 5478.25 5402.95 9953.64 5542.08 5466.78 10048.45 5608.17 5532.87 10141.21 5674.02 5598.72 10232.35 5741.05 5665.75 47 19 45 47 45 49 43 42 41 33 S 86.53 E 2.45 541.55S 7399.26E S 87.60 E 1.86 545.01S 7466.57E S 89.05 E 1.10 546.99S 7534.51E S 88.60 E 2.30 548.33S 7599.81E S 87.97 E 2.41 550.17S 7661.50E 7418.60 7485.96 7553.83 7619.00 7680.63 10325.96 5811.96 5736.66 10416.60 5882.35 5807.05 10509.80 5956.70 5881.40 10602.13 6031.68 5956.38 10695.19 6108.23 6032.93 39 57 38 7 36 1 35 22 33 54 'S 85.15 E 2.61 553.81S 7722.48E S 83.13 E 2.45 559.62S 7779.25E S 83.52 E 2.28 566.15S 7835.05E S 84.97 E 1.15 571.56S 7888.65E S 86.25 E 1.76 575.62S 7941.39E 7741.70 7798.77 7854.91 7908.78 7961.67 sr .'-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KRU / 3K-26 500292276400 NORTH SLOPE BOROUGH COMDUTATI ON DATE: 6 / 10 / 97 DATE OF SURVEY: 052897 MWD SURVEY JOB NUMBER: AK-MM-70145 KELLY BUSHING ELEV. = 75.30 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 10788.77 6187.80 6112.50 29 33 S 87.31 E 4.69 578.41S 7990.52E 10879.14 6267.05 6191.75 27 51 S 86.98 E 1.90 580.57S 8033.87E 10973.54 6351.16 6275.86 26 8 S 86.83 E 1.80 582.88S 8076.66E 11066.42 6434.66 6359.36 25 47 S 87.12 E .41 585.03S 8117.27E 11158.82 6518.78 6443.48 23 4 S 86.47 E 2.96 587.15S 8155.42E VERT. SECT. 8010.86 8054.24 8097.07 8137.72 8175.92 11249.96 6603.03 6527.73 21 45 S 86.68 E 1.45 589.23S 8190.10E 11625.06 6952.40 6877.10 20 55 S 86.97 E .22 596.80S 8326.39E 11690.00 7013.06 6937.76 20 55 S 86.97 E .03 598.02S 8349.56E 8210.65 8347.09 8370.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8370.94 FEET AT SOUTH 85 DEG. 54 MIN. EAST AT MD = 11690 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 94.82 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 11,690.00' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. OperAtions Performed: Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown ~ Stimulate Alter casing Repair well 5. Type of Well: Development __ Exploratory _ Stratigraphic _ 99510 Service X 4. Location of well at surface 1272' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 679' FSL, 2071' FEL, Sec. 36, T13N, R9E, UM At effective depth 667' FSL, 1925' FEL, Sec. 36, T13N, R9E, UM .At total depth 669' FSL, 1895' FEL, Sec. 36, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 11690 7013 feet feet Plugging Perforate X Other 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3K-26 9. Permit number/approval number 97-77 10. APl number 5o-029-22764-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured I 1 6 1 1 true vertical 6939 feet feet Junk (measured) None 13. 14. Casing Length Structural Conductor 8 0' Surface 6 7 3 8' Intermediate Production 11638' Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 1 6" 129 Sx AS I 1 21' 7-5/8" 422 Sx ASLW & 6779' 600 Sx Class G w/50 Sx AS I Top Job 4.5"x5.5" 220 Sx Class G I 1 6 7 7' 121' 4099' 7001' I 1 374'- 1 1 394', 1 1 408'-1 1 428' ~_-.-.-. true vertical 671 8'-6737',6750'-6769' Tubing (size, grade, and measured depth) '¢~.,~%_ 3.5", 9.3#/ft., b-80 @ 11286' ~*.'~ Packers and SSSV (type and measured depth) ~, ¢~,,~,, . ,~\~,~' Pkr: Baker GBH-22 Locator @ 10032'; SSSV: None, Camco nipple @ 500' Stimulation or cement squeeze summary Perforate 'A' Sands on 7/22-23/97. -/'"'~ ~-'~. :' '~-~ .... Intervals treated (measured) ~,,,~ ii \ ~ ~.~_,' , ~ '¢.~"~ 1 1374'-1 1394',1 1408'-1 1428' Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ w/ DP Charges, 4 SPF, fp = 3505 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 835 1361 Subsequent to operation 0 0 3692 850 2871 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X. 16. Status of well classification as: Oil Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ///~ ~,,~¢~ I~ f_ ~. ~,,~.p ~,,.~ Wells Superintendent Signed ~- - Title Form '10-404 Rov 0~/88 Date 1%-1'7-'/7 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT __ WELL SERVICE REPORT K1(3 K-26(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-26 PERFORATE, PERF SUPPORT 0620970508.1 DATE DALLY WORK UNIT NUMBER 07/23/97; PERFORATE 'A' SAND/SIBHP 8293 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 (~) Yes' O No (~ Yes O No SWS-JOHNSON JORDAN FIELD AFC# CCC DAILY COST ACCUM COST Signed ESTIMATE AK8805 230DS36KL $1 2,851 $47,643 Initial Tb_q Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 600 PSI 0 PSI 0 PSI 0 PSII 550 PSII 0 PSI DAILY SUMMARY I PERFED 11'374''11'394'' 2 1/8'' EJ DP' 4 SPF' +/' 45 DEG FLSH' SIBHP AT 11,400'=3505 PSI. TEMP=d 62 DEG/F. TIME LOG ENTRY 08:00 MIRU SWS 8293, JOHNSON. TGSM. PT LUB/BOP'S TO 3000#. 09:00 RIH W/GUN #1. CCL/MPD/20' X 2 1/8" EJ DP (90 DEG. PHASED), 4 SPF. TIED INTO CMT 7/22/97. PERFED 11374'-11397' +/- 45 DEG LSH. ........ ~.-.. ~O;~, ALL SHOTS FIRED. 12:30 ?.!!4 W/WTBAR/CCL-GR/PRESS/TEMP. LOG SBHP AT 11400' INITIAL PRESS=3800 PSI. STBY TO STABALIZE WELL. 15:00 LOG PRESS/TEMP 30 MIN.,. FINAL PRESS=3505 PSI. TEMP=162 DEG/F. POOH 17:00 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $500.00 $6,500.00 DIESEL $0.00 $500.00 DOWELL $0.00 $4,444.00 HALLIBURTON $0.00 $635.00 LIq-FLE RED $0.00 $1,000.00 SCHLUMBERGER $12,351.00 $34,565.00 TOTAL FIELD ESTIMATE $12,851.00 $47,644.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT __ WELL SERVICE REPORT K1(3 K-26(W4-6)) WELL JOB SCOPE JOB NUMEJER 3K-26 PERFORATE, PERF SUPPORT 0620970508.1 DATE DAILY WORK UNIT NUMBER 07/22/97; CEMENT BOND LOG, 2 1/8" EJ PERFORATE 8293 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 O Yes- (~ No ~ Yes O No SWS-JOHNSON JORDAN FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE AK8805 230DS36KL $18,11 9 $34,792 Initial Tb_q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 600 PSI 0 PSI 0 PSII 550 PSII 550 PSI DAILY SUMMARY CEMENT GOOD OVER ENTIRE 4 1/2" LINER PERFORATED 11408' TO 11428' TIME LOG ENTRY 09:00 MIRU SWS UNIT 8293; ENG: JOHNSON 10:30 RIH WITH CENT/TEL CART/CENT/CMT/CENT MAX OD= 1 11/16" 11:15 TAG TD AT 11577' BEGIN LOGGING REPEAT SECTION FROM 11566' TO 11300' LOG MAIN PASS FROM 11566"i'O 11150' 12:10 POOH 13:30 OUT OF HOLE PUT TOGETHER LOG AND MAKE PRINTS SET UP PERF EQUIP 16:00 PRESSURE TEST RISER/BOP TO 3000# 16:30 RIH WITH 6'X1 11/16" WT/20' 2 1/8" ENERJET PERF GUN 4 SPF, DP CHARGES, 90 DEG PASE 16:50 'TIE INTO CMT DATED 7/22/97 LOG TIE IN PASS . PRESSURE TUBING UP TO 1300# WITH TRIPLEX PUMP 17:30 PERFORATE 11408' TO 11428' 17:40 POOH 19:10 RDFN, SHOOT SECOND INTERVAL IN MORNING. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $0.00 $6,000.00 DIESEL $0.00 $500.00 DOWELL $0.00 $4,444.00 HALLIBURTON $0.00 $635.00 LR-FLE RED $0.00 $1,000.00 SCHLUMBERGER $18,119.00 $22,214.00 TOTAL FIELD ESTIMATE $1 8,119.00 $34,793.00 10/14/97 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11439 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk ,, ' . 1E-32 ~"~ - i ?.~..,J. CBL 970828 1 1 3K-26 ,¢1""7 '- ()"')'"--I CEMENT MAPPING TOOL 970722 I 1 ,,, 3K-30 ci'~ ~-I1.~ CEMENT MAPPING TOOL 970721 I I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: R CE VED OC'f' ] 5 '1997 9/22/97 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11366 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1B-8A ~"/- IIo~. CEMENTBOND LOG 970811 I 1 1Q-08A c~'7- O~;~ STATIC BOTTOM HOLE SURVEY 970729 1 1 1R-34 (~- / (,, ~. GAS LIFT SURVEY 970810 I 1 3F-12 Z~' ~'-/~, [.,t, tC_._.. INJECTION PROFILE 970619 I 1 31-02 '~ :-'-% - ~>~ '~ I.~ t ~ INJECTION PROFILE 97081 8 I 1 31-06 ~ ~ -- O~ ~ [),.~ C._.. INJECTION PROFILE 970708 I 1 3K-23 ~-~- Ocl~ . CEMENT EVALUATION LOGW/GR 970629 I 1 3K-23 ~ CEMENT BOND LOG W/GE 970629 I 1 3K-26 ~'1 - O-~'-] STATIC BHP LOG 970723 I 1 3M-17 ~ "/ - O~C{ GAS LIFTSURVEY 970707 I 1 3 M- 23 C[ '~ - I ~-'J GAS LIFT SURVEY 970704 I 1 3N-03 ~(o- OJ~ (J,I C-~ INJECTION PROFILE 970703 I 1 3N-7 ~ (~ - O~ PRODUCTION PROFILE 970702 I 1 3N-7 ',t,,' DEFT LOG 970702 1 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: RECEIVED SEP 2 9 ]997 Oil & Gas ¢,o~'ls. Com~$sion Anchorage 0 !:t I I--I--I N G S ~: I::!~ I C Ec: WELL LOG TRANSMITTAL To: State of Alaska August 20, 1997 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 C.~5 RE: MWD Formation Evaluation Logs 3K-26, AK-MM-70145 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Fan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3K-26: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22764-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22764-00 1 Blueline 1 Folded Sepia Blueline Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 o (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc.._Company 0 I::! I I_1-- I I~1G SGI:IL~I C ~ S WELl__, LOG TRANSNHTT_ _~ To: State of Alaska August 20, 1997 Alaska Oil and Cms Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 C~ ' (49 MWD Formation Evaluation Logs 3K-26, AK-MM-70145 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22764-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 _ A Dresser Industries, Inc. Company spemm -sur, r'l I::i I I_1_ I IM G S ~::: I::! ~/I C ~:: S June 10, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 3K-26 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 3K-26 Tie in point 0.00', to interpolated depth at 11,690.00' Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska TO: David Joh~ Chairman THRU: Blair Wondzell, P. I. Supervisor Alaska Oil and Gas Conservation Commission DATE: May 23, 1997 FILE NO: acxlewef, doc FROM: John Spaulding ~"~_. SUBJECT: Petroleum Insp.~' BOPE Test Parker 245 ARCO / KRU / 3K-26 PTD- 97-77 Friday May 23, 1997: I traveled to ARCO's Kuparuk River Unit to witness the BOPE Test on Parker Rig 245. The AOGCC BOPE Test Report is attached for reference. The choke was tested while waiting on the surface cement job to set up. I was not able to witness this portion of the BOPE Test, I was given the opportunity to review the chart and found the test to be ok. The rest of the test went quite well. I found the rig to be/~' quite clean and in very good shape with good access. Summary: I witnessed the successful BOPE Test on Parker 245, 5123197, Test Time 2 hours, 0 failures Attachments: acxlewef, xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 7 5/8" Test: Initial X Workover: Parker Rig No. 245 PTD # 97.77 ARCO Co. Rep.: 3K-26 Rig Rep.: Set @ 6, 779' md Location: Sec. Weekly Other DATE: 5/23/97 Rig Ph.# 659-7670 Donnie Luttrick Fred Hebert 35 T. 13N R. 9E Meridian UM TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign ok Drl. Rig ok Hazard Sec. ok , Quan. Test Press. P/F 300/3,000 P 500/3,000 P 500/3,000 P 500/3,000 P 500/3,000 P 500/3,000 P 500/3,000 P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/3,000 P 500/3,000 P 50O~3,OOO P 500/3,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 500/5,000 P/F 500/5,000 Func~oned Func~oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,950 P 1,600 P minutes 44 3 minutes 30 yes Remote: 2000, 2300, 2350, 2350, 2400, 2200 Psig. sec. sec. yes TEST RESULTS Number of Failures: 0 ,Test Time:(" 2.0 )Hours. Number of valves tested 12 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the A©GCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Choke was tested and charted during the surface cement job and ~v~ I did not witness the test although I reviewed the chart and found it to be ok Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev.12/94) ACXLEWEF.XLS TONY' KNOWL£$, GOVEF~NOI~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 25, 1997 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3K-26 ARCO Alaska, Inc. Permit No: 97-77 Sur. Loc.' 1272'FSL, 317'FWL, Sec. 35, T13N, R9E, UM Btmhole Loc: 569'FSL, 1906'FEL, Sec. 36, T13N, R9E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity, Test (FIT) - cementing records, FIT data, and any CQLs are to be submitted to the Commission prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. S' Chairman_ ~_ ) BY ORDER OF THE ISSION dlffenclosures cc~ Department of Fish & Game. Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~.,~N PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill E] I lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [~ Deepen []I Service [] gevelopmentGas r~ Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. Ri~! RKB 41', Pad 34' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25519, ALK 2555 4. Location of well at surface 7. Unit or property Name I 1. Type Bond (see 20 AAC 25.025) 1272' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 578' FSL, 2012' FEL, Sec. 36, T13N, R9E, UM 3K-26 #U-630610 At total depth 9. Approximate spud date Amount 569' FSL, 1906' FEL, Sec. 36, T13N, R9E, UM 5/7/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I-VD) property line 3K-08 11698' MD 569 @ TD feet 11' @ 775' feet 2560 7003' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 64.9° Maximum~urface 2418 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 6720' 41' 41' 6761' 4085' 1820 Sx Arcticset III & HF-ERW 470 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 11259 41' 41' 11300' 6632' 120 Sx ClassG HF-ERW 6.75" 4.5" 12.8# L-80 EUE8rdM 398' 11300' 6632' 11698' 7003' Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor iSn~refrarnCeed iate . , O R I GIN A LE C E iV E D Perforation depth: measured ,kWH 2 2 1997 true vertical 20. Attachments Filing fee X Property plat E] BOP Sketch X Oiverter Sketch-X''' ~j]~i¢0-~F~m X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report r'~ 20 A-AC-'2~5-.05~' ?equirements X 21. I hereby certify that,///1, the~.~/f°re-g°~r/g is true and correct to the best of my knowledge Signed , ,~,,,~, Title Drill Site Develop. Supv. Date ~'~1'~1~ For questions, please call Denise Petrash ~ '~ Commission Use Only Permit Number Ii^PM{umber _. I ^ppro,v~al date ' ' ° - I See cover letter for ~,:~'~"' ~'7 I~''~- ~ ~ ~' -- = ~' 7 ~ ~ I 4..//.,/~M~L~I?g .... i' IOther re~ u i re ments Conditions of approval Samples required [] Yes [] No r~q[~redl [~ Yes J~ No Hydrogen sulfide measures [] Yes ~] No Directional survey required ,~ Yes E] No Required working pressure for BOPE FI 2M J~ 3M [] 5M [] 10U [~ 15M Other: Origina.! Signed By David W. Johnstonby order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 i ate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3K-26 . , . , . . . o . 10. 11. 12. 13. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (6,761')according to directional plan. Run and cement 7~5/8" casing, using stage collar placed at least 200' below the base of the permafrost, and light weight lead cement. ~~ Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to total depth (11,698) according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 4~1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: This well may be completed as either a producer or an injector. Cased hole cement bond logs will be run if the well is an injector, and/or if there are problems with the cement job. Shut in and secure well. 1 4. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3K-26 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 5O-8O* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Dri Iling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Weight up to TD 10.2 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2418 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3K-26 is 3K-08. As designed, the minimum distance between the two wells would be 11' @ 775'. Drilling Area Risks- Risks in the 3K-26 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.2 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 3K-26 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3K-26 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3K-26 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3K surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4049 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7'.625 29,7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, Inc. Pad 3K 26 slot #26 Kuparuk River Unit North Slope, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E by Baker Hughes INTEQ REPORT Your ref : 26 Version #2 Our ref : prop1793 License : Date printed : 7-Apr-9? Date created : 26-Aug-96 Last revised : 7-Apr-97 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 25 48.667,w149 45 49.2 Slot location is nTO 26 1.177, w149 45 39.898 Slot Grid coordinates are N 6008265.702, E 529307.902 Slot local coordinates are 1272.00 N 317.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of [ess than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wettpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 22 Version ~6,,22,Pad 3K 2-Apr-97 100.0 280.0 280.0 H Version #2,,H,Pad 3K 8-0ct-96 25.0 280.0 280.0 PGMS <0-9038'>,,16,Pad 3K 10-0ct-96 263.0 20.0 20.0 PGMS <0-9584'>,,17,Pad 3K 10-0ct-96 287.0 20.0 20.0 27 Version #2,,27,Pad 3K 28-Feb-97 24.8 420.0 2880.0 30 Version #2,,30,Pad 3K 18-Mar-97 125.0 360.0 2525.0 32 Version #2,,32,Pad 3K 5-Mar-97 175.0 480.0 480.0 PGMS <0-9843'>,,18,Pad 3K 10-0ct-96 313.0 20.0 20.0 PGMS <0-9275'>,~15,Pad 3K 10-0ct-96 238.0 20.0 20.0 PGMS <0-8960'>,,14,Pad 3K 10-0ct-96 209.8 1275.0 1275.0 PGMS <0-8580'>,,13,Pad 3K 10-0ct-96 188.0 20.0 20.0 PGMS <O-7770'>,,12,Pad 3K 10-0ct-96 162.2 520.0 875.0 PGMS <O-7853'>~11,Pad 3K 10-0ct-96 132.9 925.0 925.0 PGMS <0-7300'>,,lO,Pad 3K 10-0ct-96 112.0 20.0 20.0 PMSS <5275 - 7443'>,,9,Pad 3K 10-0ct-96 31.8 825.0 825.0 PGMS <O-7580'>,,9A,Pad 3K 10-0ct-96 31.8 825.0 825.0 PGMS <O-8500'>,~8,Pad 3K 10-0ct-96 11.0 775.0 10943.7 PGMS <O-8500'>~?,Pad 3K 10-0ct-96 12.0 20.0 875.0 PGMS <O-8100'>~,6,Pad 3K 10-0ct-96 37.0 20.0 360.0 PGMS <O-8140'>,,5,Pad 3K 10-0ct-96 58.8 750.0 750.0 PGMS <0-8980'>,~4,Pad 3K 10-0ct-96 87.0 20.0 20.0 PGMS <0-8900'>,,3,Pad 3K 10-0ct-96 112.0 20.0 20.0 PGMS <0-9960'>,,2,Pad 3K 10-0ct-96 137.0 20.0 20.0 3K-35[E Version #1,,IE,Pad 3K 25-Feb-97 250.0 280.0 280.0 E Version #2,,E,Pad 3K 26-Feb-97 75.0 300.0 300.0 ITCreo[~d by fiflch For: D PETRASH] [3~te COt, ted : 7-AOr-g7 I ~ot R~are~e ;s 26 Va~on ~2. ~ C~r~not~ ar~ in feet r~rence ~ot ~26. ~ ARCO ALASKA, t Structure : Pod 5K Well : Field : Kuparuk River Unit Location : North Slope, AloskoI East (feet) -> 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 I f t I I I I I I I I I I I I I I I I I I f I I I 1272' FSL, 317' FWL ~ SEC. 35, T13N, RgE q>o 6O0 94.82 AZIMUTH RKB ELEVATION: 75' 6500 7000 7500 8000 8500 I I I I I I I I I 6O0 1200 1800 2400 3OO0 3600 4200 4800 5400 6OOO 66OO KOP TYD=?O0 TMD=700 DEP=O 5.00 9.00 15.00 21.00 DLS: 3.00 deg per 100 ft 27.00 B/ PERMAFROST TVD=1640 TMD=1683 DEP=247 35.00 39.00 45.00 51.00 60.00 EOC TVD=2429 TMD=2862 DEP=1099 T/ UGNU SNDS WD=2677 TMD=3446 DEP=1627 MAXIMUM ANGLE ,,= ,~.a,~ .,q*¢ DEG w SAK SNDS TVD=5408 TMD=S'67 DEP=3186 JTARGET ANGLE 7200 20 DEG ! i I i i i I I 600 0 600 1200 1800 TARG~ LOCATION: 578' FSL, 2012' FEL SEC. 56, T15N, RgE TARO~ ~D=6710 TMD= 11586 DEP=8260 SOUTH 694 EAST 8251 B/ W SAK SNDS TVD=3885 TMD=6291 OEP=4202 7 5/8" CSG PT TVD=4085 TMD=6761 DEP=4629 5OO o 500 V 1000 TD LOCATION: 569' FSL, 1906' FEL SEC. 36, T15N, R9E R£ £1VED · .'::tFR 2 2 1997 4la,~ka Oil & Gas Cons. Cornmiss~, Anchorage BEGIN ANGLE DROP TVD=5096 TMD=9145 DEP=6785 64.00 58.00 CAMPANIAN T. SND$ TVD=5897 TMD=104-49 DEP=7802 52.00 B/ HRZ TVD=624-5 TMD=10872 OEP=8042 K-1 MARKER TVD=6333 TMD=10975 DEP=8091 T/ UNIT O TVD=6448 TMD-11102 DEP=8150 ~I/Z" ~'/~-~ ~0 ~:;~'. T/ UNIT C TVD=6558 TMD=11222 DEP=8200 ¢ l"tV~:|l~ ~'~-..~.~ UNIT B TVD=6600 TMD=11268 DEP=8217 ~Tk/~ lolo~'J. -- ""-T/ UNIT A -rvo=6695 TMD=11370 DEP=8254 TARGET T/ A3 INT(EOD) TVD=6710 TMD=l1386 DEP=8260__ B/ KUP SNDS TVD=6815 TMD=11498 OEP=8298 TD TVD=7003 TMD=1t698 DEP=8367 i I i I I i I i i i i I i i i I I I I I i 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Vertical Section (feet) -> Azimuth 94.82 with reference 0.00 N, 0.00 E from slot #26 48.00 DLS: 2.00 deg per 100 ft 44.00 40.00 36.00 32.00 28.00 24.00 8400 9000 For: D PETRASItI Dote plot. t~d: 7-Apr-fl? I Structure : Pad 3K Well : Field : Kuparuk River Unit Location : North Slope, Alaska/ ~ 20 0 20 I V 40 East Lteet) - 100 80 60 40 20 0 20 40 60 BO 100 120 140 160 180 200 220 240 260 280 300 120 I I I I ~ t i r i t ~ _~, i t , i i i i i i i ~ i ~ i i J i i i t i i i i i I i 120 ,ooo ........ goo oo 12soo ............... 2~00 700~ 2300 BO0 ........... 37~ 4o . '- ~oo 2000 3400 1900 3~00 1600 1700 1800 ~ ~o0o ' 5000 60 4600 450( 60 80 80 100 100 :500 120 ~00( 800 900 1000 1100 1200 1300 ._2EO .................................................................................................................. ' ........~ 120 2500 100 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 Eesf (feel) -> 20 0 0 :D" 20 (1) I 40 V 7 , 6 4 I3 2 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST. 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMSAND HCR VALVES ON KILLAND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSIAS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-,.5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR KUPARUK RIVER UN, i' 20" DIVERTER SCHEMATIC 6 I4 I 5 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE ~ OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16"OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 WELL PERMIT CHECKLISToo Y FIELD & POOL ADMINISTRATION 1 2 3 4 5 6 7 8 9 10 11. 12. 13. Permit fee attached .................. -] Lease number appropriate ............... 'l 'I Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. . Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING REMARKS ~APPR D~~ 14. Conductor string provided ............... N 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed. 23. If diverter required, is it adequate. .'.'.'.'.'.'.'.'.'~ N 24. Drilling fluid program schematic & equip list adequate i Y~ N 25. BOPEs adequate .................... N 26. BOPEpressratingadequate;testto ~psig.~N~/ 27. Choke manifold complies w/API RP-53 (May'~) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N /,% 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... 34. Contact name/phone for weekly progress reports . . ~ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~ ~ mcm ~. Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Aug 15 13:11:03 1997 (e Reel Header Service name ............. LISTPE Date ..................... 97/08/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Technical SerVices Tape Header Service name ............. LISTPE Date ..................... 97/08/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Comment Record 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: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 5 AK-M~4-70145 S. BURKHARDT LUTRICK/BREE MSL 0) M C OF LMED Date /" ~ '" OI 3K-26 500292276400 ARCO ALASKA, INC. SPERRY-SUN DRILLING 15-AUG-'97 SERVICES 35 13N 09E 1272 317 .00 75.30 34.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 6779.0 6.750 11690.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1-3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 4 MADE NO FOOTAGE, AND IS NOT PRESENTED. 5. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. DEPTH SHIFTING/CORRECTION IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND DENISE PETRASH OF ARCO ALASKA, INC. ON 7/18/97. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1690'MD, 7013'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 6737.0 FET 6744.0 RPD 6744.0 STOP DEPTH 11638.5 11645.5 11645.5 RPM 6744.0 RPS 6744.0 RPX 6744.0 ROP 6789.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 11645.5 11645.5 11645.5 11691.0 - EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 5 6789.0 11690.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FTkH 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD O}iMM 4 1 68 20 6 RPD MWD OHM~ 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Min 6737 9 6064 30 1132 0 6115 0 7613 0 1007 0 0541 0.123 First Max Mean Nsam Reading 11691 9214 9909 6737 567.968 168.038 9805 6789 466.788 103.251 9804 6737 2000 3.48236 9804 6744 2000 4.74137 9804 6744 2000 10.1763 9804 6744 2000 14.8447 9804 6744 65.5032 1.25626 9804 6744 Last Reading 11691 11691 11638.5 11645.5 11645.5 11645.5 11645.5 11645.5 First Reading For Entire File .......... 6737 Last Reading For Entire File ........... 11691 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Conunent Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6737.0 11638.5 FET 6744.0 11645.5 RPD 6744.0 11645.5 RPM 6744.0 11645.5 RPS 6744.0 11645.5 RPX 6744.0 11645.5 ROP 6789.0 11691.0 $ LOG HEADER DATA DATE LOGGED: 28-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.17f DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11690.0 TOP LOG INTERVAL (FT) : 6789.0 BOTTOM LOG INTERVAL (FT) : 11690.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.9 I~AXIMUM ANGLE: 72.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 ISC 4.88/5.06 CIM 5.46/SP4 5.03/DEPII TOOL NUMBER P0715SP4 P0715SP4 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 (O~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.750 6.8 LSND-HT 196.20 51.0 9.0 450 4.4 3.200 1.961 4.000 2.300 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 RPX MWD 5 OHMM 4 1 68 8 3 RPS MWD 5 OHMM 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD MWD 5 OHM>4 4 1 68 20 6 ROP MWD 5 FTkH 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 51.7 First Name Min Max Mean Nsam Reading DEPT 6737 11691 9214 9909 6737 GR 30.1132 466.788 103.251 9804 6737 RPX 0.6115 2000 3.48236 9804 6744 RPS 0.7613 2000 4.74137 9804 6744 Last Reading 11691 11638.5 11645.5 11645.5 RPM 0.1007 2000 10.1763 9804 RPD 0.0541 2000 14.8447 9804 ROP 9.6064 567.968 168.038 9805 FET 0.123 65.5032 1.25626 9804 6744 6744 6789 6744 11645.5 11645.5 11691 11645.5 First Reading For Entire File .......... 6737 Last Reading For Entire File ........... 11691 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reek Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File