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Home My WebLink About196-178Originated: Delivered to:2-Sep-25Alaska Oil & Gas Conservation Commiss02Sep25-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCD4-24 50-103-20602-00-00 209-097 Colville River WL RBP FINAL FIELD 3-Aug-251E-36 50-029-22927-00-00 198-213 Kuparuk River WL WFL FINAL FIELD 5-Aug-252F-18 50-029-22720-00-00 196-178 Kuparuk River WL SCMT FINAL FIELD 6-Aug-251E-36 50-029-22927-00-00 198-213 Kuparuk River WL RST FINAL FIELD 7-Aug-251C-121 50-029-23015-00-00 201-080 Kuparuk River WL IPROF FINAL FIELD 8-Aug-252V-16 50-029-21296-00-00 185-033 Kuparuk River WL PPROF FINAL FIELD 9-Aug-252X-01 50-029-20963-00-00 183-084 Kuparuk River WL HEX-PLUG FINAL FIELD 10-Aug-251R-22A 50-029-22206-01-00 199-049 Kuparuk River WL PPROF FINAL FIELD 11-Aug-251C-121 50-029-23015-00-00 201-080 Kuparuk River WL IPROF FINAL FIELD 13-Aug-251B-08A 50-029-20635-01-00 197-112 Kuparuk River WL IPROF FINAL FIELD 22-Aug-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T40840T40841T40842T40841T40843T40844T40845T40846T40843T408472F-1850-029-22720-00-00196-178Kuparuk RiverWLSCMTFINAL FIELD6-Aug-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.09.03 08:58:49 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, March 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2F-18 KUPARUK RIV UNIT 2F-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/26/2025 2F-18 50-029-22720-00-00 196-178-0 N SPT 5739 1961780 2500 0 2660 2590 2560 160 480 480 480 OTHER P Austin McLeod 2/12/2025 CMIT TxIA. "BiSN" (beads) patch. Sundry # 324-051. 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 2F-18 Inspection Date: Tubing OA Packer Depth 10 2655 2580 2550IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250212181623 BBL Pumped:3 BBL Returned:2.7 Wednesday, March 26, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 :HOOLVD6XVSHQGHG2LOSURGXFHU James B. Regg Digitally signed by James B. Regg Date: 2025.03.26 10:58:24 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 121' 9-5/8" L-80 3161' 7" L-80 5923' 5" L-80 6436' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate TUBING RECORD 41' 8.5" 12.25" 28 sx AS I 41'330 sx ASLW, 1220 sx Class G w/60 sx AS I tail 137 sx Class G6.125" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 2/12/2025 196-178/ 324-051 ALK 2587 12/22/1996 9715' MD/ 6385' TVD 7958' MD/ 4875' TVD P.O. Box 100360, Anchorage, AK 99510-0360 517519 5948608 CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, KRU 2F-18 ADL0025666 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM 1296' FNL, 659' FEL, Sec. 4, T10N, R9E, UM 9. Ref Elevations: KB: 138' BOTTOM 1127' FNL, 693' FEL, Sec. 4, T10N, R9E, UM 50-029-22720-00-00 CASING WT. PER FT.GRADE 1/16/1997 CEMENTING RECORD 5942479 1650' MD/ 1525' TVD SETTING DEPTH TVD 5942310 TOP HOLE SIZE AMOUNT PULLED 518568 518603 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A Kuparuk River Field/ Kuparuk River Oil Pool DEPTH SET (MD) 8935' MD/ 5738' TVD PACKER SET (MD/TVD) 24" If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run):8979'3-1/2" 26# 9715' 39' 5739' 62.5# 130 sx Class G 40# 121' 39' 9140' 8746' Top of BiSN (Tubing) SUSPENDED Perforations: 9325-9335' MD and 6086-6095' TVD Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. 18# 41' 8935' 5614'41' SIZE Sr Res EngSr Pet GeoSr Pet Eng 523' MD/ 523' TVD Oil-Bbl: Water-Bbl: 0.1 bbls BiSn 7958-7964' (IA) 7 ft =0.19 bbl BiSN beads Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 2:51 pm, Mar 13, 2025 Suspended 2/12/2025 JSB RBDMS JSB 032425 xGDSR-4/7/25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1650' 1525' Top of Productive Interval 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: Katherine.OConnor@conocophillips.com Contact Phone: 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: N/A - Suspended INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov N/A - Suspended Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2025.03.13 13:56:11-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Identify Bead Location in IA and Melt Beads 2F-18 2/7/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 BAKER 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) 7,958.0 4,875.4 28.51 TUBING PUNCH 1 FT OF 2" TUBING PUNCH, 7 GRAM KNOCKOUT (#2), 4 SPF, 0 DEGREE PHASE, 0.61" HOLE SIZE 12/23/2024 2.992 7,958.0 4,875.4 28.51 TUBING PUNCH 1 FT OF 2" TUBING PUNCH, 7 GRAM KNOCKOUT, 4 SPF, 0 DEGREE PHASE, 0.61" HOLE SIZE 12/23/2024 2.992 8,727.0 5,553.3 27.72 PLUG MILLED & PUSHED 2/2/25, NSAK composite bridge plug (OAL 1.3') 2/2/2025 0.000 8,746.4 5,570.4 27.58 PLUG BiSN ALLOY PLUG, 2.58' OAL BiSN AOH 5/6/2024 0.000 8,885.0 5,693.6 27.06 TUBING PUNCH 3' x 1.56" TUBING PUNCHER, 4 SPF, 3.4g HMX, 0.43" EH GEODY NAMICS TG39CM 2 N/A 5/29/2023 2.992 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,242.6 2,669.7 69.85 1 GAS LIFT DMY BK 1 0.0 11/30/2023 6:00 0.000 6,783.6 3,855.2 36.58 2 GAS LIFT DMY INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT DMY BK 1 0.0 10/28/2024 7:00 0.000 8,504.3 5,356.8 28.25 4 GAS LIFT DMY BK 1 0.0 11/28/2023 8:00 0.000 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 60 deg phase MULTIPLE LATERALS, 2F-18, 3/10/2025 12:35:36 PM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 FRAC; 9,325.0 APERF; 9,325.0-9,335.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,749.0 8,888.0 5,572.7 5,696.3 Cement Plug 6/3/2023 7,990.0 8,888.0 4,903.5 5,696.3 Cement Plug 6/3/2023 7,658.0 7,664.0 4,612.1 4,617.4 Remedial PRE-MELT BEADS IDENTIFIED AT 7658' TO 7664' 2/7/2025 7,960.0 7,975.0 4,877.2 4,890.3 Remedial 794 LBS OF BISN BEADS 1/25/2025 7,975.0 8,000.0 4,890.3 4,912.3 Remedial 5/1/2024 MULTIPLE LATERALS, 2F-18, 3/10/2025 12:35:37 PM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 FRAC; 9,325.0 APERF; 9,325.0-9,335.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD 2F-18 ... WELLNAME WELLBORE2F-18 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 3/10/2025 12:35:38 PM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 3/10/2025 12:35:38 PM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 3/10/2025 12:35:39 PM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 1/30/2024 OPTIMIZE WELL PERFORM CBL TAG TOC IN TBG AT 8750' AND LOG MAIN PASS FROM 8750'-7750' TOC IN IA IDENTIFIED AT 7990' JOB COMPLETE 4/14/2024 ACQUIRE DATA PULL 1" DUMMY VLV FROM STA 3 @ 7768' RKB & REPLACE W/ CIRC VLV. BAIL CEMENT FROM TOP OF CATCHER @ 8751' RKB, JOB IN PROGRESS 4/15/2024 ACQUIRE DATA BAIL CEMENT FROM TOP OF AVA CATCHER @ 8751' RKB. PULL 3.5" AVA CATCHER FROM TOC @ 8751' RKB. READY FOR CIRC OUT. 4/19/2024 REPAIR WELL CIRC-OUT WELL PUMPED 311 BBLS INHIBITED SEAWATER DOWN TBG TAKING RETURN UP IA, FOLLOWED BY 200 BBLS DIESEL, ALLOW TBG AND IA TO U-TUBE FOR FREEZE PROTECT. JOB COMPLETE 5/1/2024 ACQUIRE DATA LOADED 794 LBS (180 KG) OF BISN BEADS INTO IA. 5/1/2024 ACQUIRE DATA CIRC OUT 200 BBLS SLICK CISW FOLLOWED BY 100 BBLS DSL DOWN IA TAKING RETURNS UP TBG. U-TUBE TBG AND IA. TEMP FREEZE PROTECT FLOWLINE WITH DSL FREEZE PROTECT FL WITH METH. JOB COMPLETE 5/5/2024 REPAIR WELL LOG CBL OVER INTERVAL 8090' - 7700', OVERLAY GR WITH CBL LOG DATED 30-JAN-2024 PRE BEAD DROP, NO CLEAR INDICATION OF BEAD LOCATION IN IA, LOG GR WHILE POOH TO SURFACE AND OVERLAY WITH LDL LOG DATED 27-AUG-2022 UPLOAD DATA FOR ANALYSIS AND PLAN FORWARD JOB CONTINUED NEXT DAY 5/6/2024 REPAIR WELL RUN BISN TUBING SEAL TOOL AND HEATER, SIT DOWN AT BTM @ 8749' AND ACTIVATE HEATER, GOOD INDICATION AFTER FIRING BY 6FT DEEPER PICKUP AND 100LBS LESS UP TENSION, NO ISSUES DRAGGING WHILE POOH JOB CONTINUED NEXT DAY 5/7/2024 REPAIR WELL LRS PUMP DOWN IA IN STAGES TAKING RETURNS OFF TUBING TO FLOWLINE TO TRY AND PUSH BISN BEADS TO DEPTH, SLB ELINE LOG GR AND OVERLAY BETWEEN PUMPING TO TRY AND IDENTIFY BEAD LOCATION, BISN BEAD LOCATION NOT SEEN ON GR OVERLAYS, UPLOAD DATA FOR FURTHER ANALYSIS, TOTAL OF 10 BBL HI-VIS PILL AND 160 BBL DIESEL PUMPED DOWN IA (U-TUBE WELL). JOB IN PROGRESS 5/10/2024 ACQUIRE DATA (AC EVAL) CDDT T X IA TO 0 PSI (IN PROGRESS) 6/18/2024 REPAIR WELL RUN BISN RUNNING TOOL & HEATER LOG CORRELATED TO AKE CBL DATED 30-JAN-2024 POSITION TOOLS W/ CCL OFFSET=23.8', HEATER BOTTOM=7987', CCL STOP DEPTH=7963.2' ACTIVATED HEATER & WAITED 30 MIN TOOLS STUCK AT MELTING DEPTH, PULLED OUT OF ROPE SOCKET, TOOLSTRING LEFT IN HOLE OAL: 26.3', OAW ~300 LBS, MAX OD: 2.625", FN: 1" DHD TO PERFORM DDT 6/19/2024 REPAIR WELL (AC EVAL) CDDT T X IA TO 0 PSI (IN PROGRESS) 8/10/2024 REPAIR WELL RECOVERED E-LINE TOOL STRING/ BISN HEATER TOOL FISH (OAL 26.3' ) @ 7960' RKB. RIG DOWN, WAIT FOR PLAN FORWARD. 10/1/2024 MAINTAIN WELL FREEZE PROTECT FLOWLINE PUMPED 20 BBLS METH DOWN FLOWLINE AND .5 BBLS METH DOWN TBG JOB COMPLETE 10/29/2024 REPAIR WELL TAG BiSn BEADS @ 8746' RKB. PULL HFCV FROM STA 3 @ 7768' RKB. ATTEMPT TO SET DUMMY VLV IN STA 3, JOB IN PROGRESS 10/30/2024 REPAIR WELL SET 1" DMY IN STA 3 @ 7768' RKB. ATTEMPT MIT-T TO 2500 PSI (FAILED), RIG DOWN FOR HIGHER PRIORITY WORK. 11/11/2024 REPAIR WELL RAN HOLE FINDER TO TOP OF BISN BEADS & APPEARED TO BE GETTING A GOOD TEST. PULLED OUT OF HOLE & ATTEMPTED MITT TO 2500 PSI **FAIL**. RE-RAN HOLE FINDER & SUSPECT LEAK IS DV IN STA #3 @ 7768' RKB, SET AVA CATCHER ON TOP OF BISN BEADS, PULL DV FROM STA #3 @ 7768' RKB. IN PROGRESS 11/12/2024 REPAIR WELL SET 1'' BK DMY VLV IN ST#3 @ 7768' RKB, PERFORMED MIT-T TO 2500 PSI **PASS**. PULLED CATCHER @ 8746' RKB, READY FOR STATE W. TAG & TEST 2F-18 BiSN Suspend Summary of Operations 11/15/2024 REPAIR WELL PERFORM STATE WITNESS TAG TOC @ 8245' RKB (RECOVER 1/2 GAL CEMENT), GET PASSING STATE WITNESS MIT-T 2500 PSI. RDMO. 11/18/2024 ACQUIRE DATA (PRE RWO) T DDT (COMPLETE) 12/23/2024 REPAIR WELL SHOT TUBING PUNCH INTERVAL 7958'-7959' TWICE W/ 2" PUNCHERS LOADED 1' W/ 7 GRAM KNOCKOUT CHARGES (.61" ENTRANCE HOLE OD) LOG CORRELATED TO TUBING TALLY DATED 1/16/1997 WELL LEFT S/I JOB CONTINUED 12/24/2024 12/24/2024 REPAIR WELL SET NORTHERN SOLUTIONS 350-273 COMPOSITE BRIDGE PLUG AT 7960' (1' BELOW BOTTOM TUBING PUNCH HOLES) LOG CORRELATED TO TUBING TALLY DATED 1/16/1997 WELL LEFT S/I. READY FOR CIRC OUT. 1/6/2025 REPAIR WELL CIRC OUT WELL PUMP 240 BBLS CISW DOWN TUBING TAKING RETURNS OFF IA TO ADJACENT WELL FLOWLINE, FOLLOWED BY 40 BBLS DSL AND U-TUBED FOR BALANCE. 1/21/2025 REPAIR WELL DRIFT TBG TAG TOP OF CBP @ 7960' RKB. DUMP BAIL BISN BEADS (2 RUNS) & PUMP DOWN TBG TAKING RETURNS FROM IA. LAST TD W/ BAILER @ 7957' RKB, U TUBE TBGxIA, JOB IN PROGRESS 1/22/2025 REPAIR WELL DUMP BAIL APPROX 6 GAL OF BISN BEADS & PUMP DOWN TBG TAKING RETURNS FROM IA @ 7958' RKB. FP & U TUBE TBGxIA JOB IN PROGRESS 1/23/2025 REPAIR WELL DUMP BAIL APRROX 6 GAL OF BISN BEADS & PUMP DOWN TBG TAKING RETURNS FROM IA @ 7987' RKB, FP & U TUBE TBGxIA, JOB IN PROGRESS 1/25/2025 REPAIR WELL DUMP BAIL ~6 GAL OF BISN BEADS & PUMP DOWN TBG TAKING RETURNS FROM IA @ 7,958' RKB, LRS U-TUBE TBGxIA, DRIFT TO AND TAG BISN BEAD ON TOP OF CBP @ 7,960' RKB. COIL UP NEXT TO MILL CBP. 1/30/2025 REPAIR WELL TRAVEL FROM 2M-PAD TO 2F-18. 1/31/2025 REPAIR WELL RIG UP CTU 6 W/ 11,476' OF 1.75" CT (21 BBLS FUV) & STAND BY DUE TO WEATHER TEMPERATURE IN EXCESS OF -35*F. IN PROGRESS. 2/1/2025 REPAIR WELL WEATHER DELAYED, AMBIENT TEMP BELOW -35*F; PERFORM WEEKLY BOP TEST. RIH W/ 2" DJN & TAG BiSn BEADS @ 7883' CTMD & PREPARE TO REVERSE CIRCULATE. IN PROGRESS. 2/2/2025 REPAIR WELL REVERSE CIRCULATED 33' OF BISN BEADS FROM 7883' TO HARD TAG @ 7916' CTMD. MILL COMPOSITE PLUG AT 7959' RKB AND PUSH TO 8730' RKB (TOP OF BISN/CEMENT PLUG). READY FOR CIRC OUT & ELINE 2/3/2025 REPAIR WELL CIRC OUT WELL PUMPED 280 BBLS SLSW DOWN TBG AND UP IA FOLLOWED BY 70 BBLS DSL. U-TUBED FOR FREEZE PROTECT JOB COMPLETE 2/7/2025 REPAIR WELL RUN 1: PERFORM GR/CCL LOG, BiSN BEADS LOCATED IN IA BETWEEN 7958'-7964'. (TOC IN IA AT 7990') CONFER WITH CWG, DECISION MADE TO PROCEED WITH MELTING BEADS. RUN 2: PLACE BOTTOM OF BiSN HEATER AT 7966'. APPLY POWER AND WAIT 30 MIN. TOOLSTRING STUCK WHEN READY TO POOH. PULLED TO WEAKPOINT BEAKING STRENGTH AND TOOLS STARTED MOVING. HEAVY TENSIONS OUT OF HOLE, PULLED TO UPPER WEAKOINT MULTIPLE TIMES. ALL TOOLS RECOVERED AT SURFACE. HEATER WAS BENT. JOB COMPLETE, READY FOR DHD 2/8/2025 REPAIR WELL (AC EVAL) : CMIT-TxIA PASSED TO 2500 PSI. T X IA DDT TO 0 PSI (IN PROGRESS). 2/9/2025 REPAIR WELL (AC EVAL) T X IA CDDT TO 0 PSI (PASSED) 2/12/2025 REPAIR WELL (SW) STATE WITNESSED ( AUSTIN MCLEOD) CMIT T X IA TO 2660 PSI (PASSED) 2/12/2025 REPAIR WELL (AC EVAL) T DDT TO 0 PSI (PASSED) IA DDT TO 0 PSI (PASSED) 1 Conklin, Amy A From:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent:Thursday, August 29, 2024 9:10 AM To:O'Connor, Katherine Subject:[EXTERNAL]RE: 2F-18 Suspension Plan Forward APPROVAL Follow Up Flag:Follow up Flag Status:Completed CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Katherine, Approval is granted for the revised procedure below. Please include this approval with your approved sundry. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Sent: Thursday, August 15, 2024 10:48 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: 2F-18 Suspension Plan Forward Hi Victoria 2F-18 is a well that had a balanced plug pumped to abandon the reservoir. The tentative future of the well is to complete a RWO sidetrack. The cement passes a positive pressure test, but does not pass a drawdown test. We planned to repair the cement using a BISN plug place in the tubing with the WellLok tool, and in the IA by pumping beads. The beads in the IA never made it down, so we weren’t able to place BISN on opt of the cement in the IA – this was a known risk because of the deviation of the well. It is “S” shaped, and the beads are likely strung out at the highest deviation area from ~3300’ – 5600’, where the deviation is 68-70 degrees. The tubing plug was successfully set. I have been working with BISN on a path forward and am requesting approval to repair the well with the following steps: 1. Set retrievable plug @ ±7965’ KB 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. 2 2. Punch tubing with big hole charges about 5’ above plug 3. Using wireline, RIH with bailer full of beads to top of plug 4. Drop beads and pump into IA 5. Place a ~10’ BISN plug on top of cement in the IA 6. Once beads are placed, RIH with heater and melt beads 7. Pull retrievable plug 8. Proceed with sundry steps to pressure test tubing and IA. Thanks Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) ORIGINATED TRANSMITTAL DATE: 2/19/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5284 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5284 2F-18 50029227200000 Hoist 7-Feb-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 196-178 T40104 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.19 15:23:59 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5215 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5215 2F-18 50029227200000 Tubing Puncher Record 23-Dec-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 196-178 T39934 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:09:31 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 33 Township: 11N Range: 9E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 9715 ft MD Lease No.: ADL0025667 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 121 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 5614 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 9142 Feet Csg Cut@ Feet Liner: 5" O.D. Shoe@ 9715 Feet Csg Cut@ Feet Tubing: 3.5" O.D. Tail@ 8979 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole Bottom 8885 ft 8745 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result MIT-T Tubing 2650 2570 2540 2530 IA 1140 1140 1140 1140 OA 240 240 240 240 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Greg Clayton Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Tagged cement at 8721 ft wireline measurement (8745 ft MD with 24-ft correction). Cement sample was mostly contaminated with signs of cured cement. Passing MIT-T. November 15, 2024 Guy Cook Well Bore Plug & Abandonment KRU 2F-18 ConocoPhillips Alaska Inc. PTD 1961780; Sundry 324-051 None Test Data: P Casing Removal: rev. 3-24-2022 2024-1115_Plug_Verification_KRU_2F-18_gc 9 9 9 9 9 9 99 9 9 9 9 9 9 9 99 99 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.22 14:14:36 -09'00' ORIGINATED TRANSMITTAL DATE: 6/25/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4885 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4885 2F-18 500292272000 Hoist (with logs) 18-Jun-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 196-178 T39045 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 08:51:24 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 Originated:Delivered to:12-Jun-24 Alaska Oil & Gas Conservation Commiss 12Jun24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD4-587 50-103-20867-00-00 223-098 Colville River WL PPROF FINAL FIELD 29-Apr-24 2F-18 50-029-22720-00-00 Kuparuk River WL CBL FINAL FIELD 5-May-24 2F-18 50-029-22720-00-00 Kuparuk River WL GR FINAL FIELD 5-May-24 WD-02 50-103-20285-00-00 198-258 Colville River WL WFL FINAL FIELD 11-May-24 2N-310 50-103-20549-00-00 207-090 Kuparuk River WL Perforation FINAL FIELD 11-May-24 CD1-01A 50-103-20299-01-00 212-099 Colville River WL WFL FINAL FIELD 13-May-24 CD1-33A 50-103-20357-01-00 222-105 Colville River WL WFL FINAL FIELD 12-May-24 Transmittal Receipt ________________________________X__________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Ousidame@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T38933 T38934 T38934 T38935 T38936 T38937 T38938 2F-18 50-029-22720-00-00 Kuparuk River WL CBL FINAL FIELD 5-May-24 2F-18 50-029-22720-00-00 Kuparuk River WL GR FINAL FIELD 5-May-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 09:21:58 -08'00' 196-178 T38890 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.11 15:12:42 -08'00' 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: BiSN 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9715'9232' 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: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3718 Well Interventions Engineer KRU 2F-18 6385' 8535' 5384' 8535' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: katherine.oconnor@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8935' MD and 5738' TVD 8951' MD and 5753' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025666, ADL0025667 196-178 P.O. Box 100360, Anchorage, AK 99510 50-029-22720-00-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool- Suspended TVD Burst 8979' MD 121' 3161' 121' 5614' 5923'9142' 16" 9-5/8" 80' 5573' 9325-9335' 9103' 5" 6086-6095' 7" Perforation Depth TVD (ft): 2/21/2024 9715'780' 3-1/2" 6385' Packer: Baker Tieback Sleeve w/ LT Packer Packer: Baker Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 11:08 am, Feb 06, 2024 324-051 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.02.06 07:22:16-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor DSR-2/13/24 See AOGCC Industry Guidance Bulletin 21-002A for additional guidance. Well-site inspection is required within 12 months after THIS suspension approval. Monthly reporting of TIO pressures required post plug. X May 23, 2028 X SFD 2/7/2024 10-407 05/23/28 Suspend VTL 02/13/24 4100 *&:JLC 2/16/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.16 13:24:06 -06'00'02/16/24 RBDMS JSB 022024 Date: 31 January 2024 Subject: 2F-18 Reservoir Abandonment Remediation Prepared by: Katherine O’Connor (214) 684-7400 Well History 2F-18 was a gas lifted producer that had a balanced cement plug pumped into the tubing and IA in summer 2023 after the wellbore got plugged off with rocks/fill. The cement passed pressure tests on the tubing and the IA. When prepping the well for a suspension inspection, it was discovered that the tubing and IA had ~1900 psi. This wellbore is currently being evaluated for either a RWO sidetrack or rotary redrill. The objective of this procedure is to place BISN plug on top of the cement plug in the IA and tubing in order to remediate the current repressurization. Notes: Tagged TOC 8737’ (135’ = 1.17 tubing cement and 885 ft IA cement Inclination Max: 71 deg @ 3950’ RKB Min ID: 2.80” Camco landing nipple @ 8942’ RKB Last SBHP 09/17/22 || 4270 psi || 8971’ RKB Repressurization rate of 5 psi/hour 12/10/23 MIT-T passed 11/30/23 MIT-IA passed 12/16/23 TOC in IA @ 8000’ KB (per CBL run 1/30/2024) Calculations Procedure: Eline 1. Tag TOC in tubing 2. Pump bismuth beads down the IA (aim is to get ~5’ worth of beads above TOC in IA) 3.Run CBL to survey bead settling depth 4.Pump down IA if needed to push beads to depth 5.Run heater to melt beads into solid patch 6.Run CBL to survey top of BISN in annulus 7.RU and RIH with BISN “tubing seal” tool and heater 8. Tag TOC and pull up ~10’ KB String Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3.5" tubing 0 8979 3.5" 9.3# 2.99" 0.0087 8884 77.2 115 tubing volume calculated from tag depth 3.5" x 7" annulus 0 8935 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 8884 234.6 38 casing volume calculated from tag depth tubing and IA had ~1900 psi. 9. Melt bismuth alloy beads and let fall on top of tubing cement plug – aim is to get at a ~5’ bismuth plug Slickline & Fullbore 1. RU Slickline and PT equipment as required 2. RIH to tag top of BISN (AOGCC witness) @ approx. 8730’ KB, record results 3. CMIT-TxIA to 2500 psi (AOGCC witness), record results 4. MIT-T to 2500 psi (AOGCC witness), record results 5. DDT-0 psi on tubing and IA, record results Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set catcher, DMY off 2F-18 11/30/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 BAKER 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) 8,532.0 5,381.1 28.39 CATCHER Set catcher on cement top. 11/27/2023 0.000 8,885.0 5,693.6 27.06 TUBING PUNCH 3' x 1.56" TUBING PUNCHER, 4 SPF, 3.4g HMX, 0.43" EH GEODY NAMICS TG39CM 2 N/A 5/29/2023 2.992 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,242.6 2,669.7 69.85 1 GAS LIFT DMY BK 1 0.0 11/30/2023 0.000 6,783.6 3,855.2 36.58 2 GAS LIFT DMY INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT DMY BK 1 0.0 11/29/2023 0.000 8,504.3 5,356.8 28.25 4 GAS LIFT DMY BK 1 0.0 11/28/2023 0.000 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 MULTIPLE LATERALS, 2F-18, 1/31/2024 11:16:25 AM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 APERF; 9,325.0-9,335.0 FRAC; 9,325.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 1/31/2024 11:16:26 AM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 1/31/2024 11:16:26 AM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 1/31/2024 11:16:27 AM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set catcher, DMY off 2F-18 11/30/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 BAKER 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) 8,532.0 5,381.1 28.39 CATCHER Set catcher on cement top. 11/27/2023 0.000 8,885.0 5,693.6 27.06 TUBING PUNCH 3' x 1.56" TUBING PUNCHER, 4 SPF, 3.4g HMX, 0.43" EH GEODY NAMICS TG39CM 2 N/A 5/29/2023 2.992 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,242.6 2,669.7 69.85 1 GAS LIFT DMY BK 1 0.0 11/30/2023 0.000 6,783.6 3,855.2 36.58 2 GAS LIFT DMY INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT DMY BK 1 0.0 11/29/2023 0.000 8,504.3 5,356.8 28.25 4 GAS LIFT DMY BK 1 0.0 11/28/2023 0.000 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,737.0 8,888.0 5,562.1 5,696.3 Cement Plug 6/3/2023 8,000.0 8,888.0 4,912.3 5,696.3 Cement Plug 6/3/2023 MULTIPLE LATERALS, 2F-18, 2/13/2024 10:50:09 AM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 APERF; 9,325.0-9,335.0 FRAC; 9,325.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,737.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 Cement Plug; 8,000.0 ftKB GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov )HEUXDU\1, 2024 Erika Livingston Wells Chief Engineer ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number OTH-23-031 Notice of Violation – Closeout Late Well Completion Report Kuparuk River Unit 2F-18 (PTD 1961780) Dear Ms. Livingston: ConocoPhillips Alaska, Inc. (CPAI) responded to the above referenced notice of violation by letter dated January 3, 2024. That letter identifies specific actions to prevent recurrence of the notice of violation, notably maintaining an internal tracker for well work activity while investigating automation solutions to provide additional assurance and redundancy for completion report deadline tracking for non-rig work. The corrective actions outlined in your letter address the procedural concerns identified in the notice of violation. The Alaska Oil and Gas Conservation Commission (AOGCC) does not intend to pursue any further enforcement action regarding this late well completion report. Sincerely, Brett W. Huber, Sr. Chair, Commissioner cc: Victoria Loepp Jim Regg Phoebe Brooks Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.01 14:37:35 -09'00' January 3, 2024 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501 VIA EMAIL aogcc.reporting@alaska.gov and samantha.carlisle@alaska.gov Re: Docket Number OTH-23-031 Notice of Violation Late Well Completion Report KRU 2F-18 (PTD 196-178) Dear Commissioner Chmielowski: This letter responds to the Alaska Oil and Gas Conservation Commission’s (AOGCC’s) letter dated December 5, 2023 regarding the above-referenced well completion report for KRU 2F-18 (PTD 196- 178).1 On November 15, 2023, ConocoPhillips Alaska, Inc. (CPAI) submitted an email to the AOGCC with the completed 10-407, explaining the reasons for the late filing. To restate, in this case, CPAI misinterpreted the Conditions of Approval on the approved sundry 323-281 to require a completion test after the well-site inspection, rather than after the well work was completed. As AOGCC points out in its December 5 letter, under applicable regulations, CPAI should have instead filed 10-407 completion report 30 days after completion and a separate 10-404 30 days after the well-site inspection. In its December 5 letter, AOGCC requests that CPAI “describe specific steps that have been or will be taken to prevent recurrence of this violation.” Responsive to this request, CPAI has implemented or will implement the following:  CPAI has identified workflow differences between rig and non-rig work that make tracking completion report deadlines more difficult in the non-rig context. We are investigating automation solutions to provide additional assurance and redundancy for completion report deadline tracking for non-rig work.  Until automation solutions are identified, CPAI will implement additional manual steps, including maintaining an internal tracker showing wellwork activity per operating area and 1 On December 12, 2023, AOGCC granted CPAI an extension to respond to the letter until January 4, 2024. Will Earhart Well Integrity and Intervention Supv P. O. Box 100360 Anchorage, AK 99510-0360 Phone 907.265.1077 William.C.Earhart@ConocoPhillips.com open approved sundries. A recurring biweekly meeting will be piloted to review the tracker with the well engineers responsible for each open sundry.  CPAI leadership has also reiterated to the entire wells team that the 10-407 is required within 30 days of completion of the operations approved within the sundry. Please reach out to myself or Greg Hobbs for any further information regarding this matter. Sincerely, Will Earhart cc: Victoria Loepp (victoria.loepp@alaska.gov) Jim Regg, AOGCC (jim.regg@alaska.gov) Phoebe Brooks, AOGCC (phoebe.brooks@alaska.gov) Digitally signed by Will Earhart DN: OU=Engineering Supv, O=Well Integrity and Intervention, CN=Will Earhart, E=william.c.earhart@ conocophillips.com Reason: I am the author of this document Location: 700 G Street, Anchorage, AK Date: 2024.01.03 10:33:06-09'00' Foxit PDF Editor Version: 13.0.0 Will Earhart 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:Loepp, Victoria T (OGC) To:Hobbs, Greg S; Regg, James B (OGC) Cc:Christianson, Grace K (OGC); Carlisle, Samantha J (OGC) Subject:RE: Dockets OTH-23-030 and OTH-23-031 Date:Tuesday, December 12, 2023 12:10:05 PM Greg, Both response requests are approved as written below. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Tuesday, December 12, 2023 12:06 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Dockets OTH-23-030 and OTH-23-031 Victoria and Jim, Dockets OTH-23-030 and OTH-23-031 were received electronically on December 6, 2023. Docket OTH-23-030 is the Notice of Investigation for Sustained Casing Pressure on KRU 3G-09 (PTD 190-067). It requested responses within 7 days of receiving the letter of NOI. At this point we have gathered the data for the response and are working on finalizing the collation and presentation. While we are close, we are respectfully requesting that this response be due on December 20, 2023 instead of December 13, 2023. Docket OTH-23-031 is the Notice of Violation for a late well completion report on well KRU 2F- 18 (PTD 1961780). It requested a response within 14 days of receiving the NOV. Both dockets involved the same team and with the focus on gathering the information on the 3G-09 NOI, no work has been done to date on this docket. It is respectfully requested that this response be due on January 4, 2024 in consideration of the Christmas and New Years Holidays. Thank-you for the consideration of these requests. Greg Greg Hobbs, P.E. Regulatory Engineer | Wells Team ConocoPhillips Alaska Inc. Office: 907-263-4749 Cell: 907-231-0515 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 5, 2023 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 2052 9563 Mr. Greg Hobbs Regulatory Engineer ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-23-031 Notice of Violation – Late Well Completion Report KRU 2F-18 (PTD 1961780) Dear Mr. Hobbs: Well suspension at Kuparuk River Unit 2F-181 was authorized by the Alaska Oil and Gas Conservation Commission (AOGCC) pursuant to Sundry 323-281, approved on May 23, 2023. Sundry approval 323-281 requires ConocoPhillips Alaska Inc. (CPAI) to submit a Well Completion or Recompletion Report and Log (Form 10-407) upon completion of the well work outlined in the sundry work plan – verification of the plug integrity with a tag and pressure test. On November 15, 2023, CPAI submitted the 10-407 late by their own assessment, noting that the instructions in the Conditions of Approval section the sundry approval included a “well site inspection must be done within 12 months”. AOGCC regulation 20 AAC 25.070 requires submittal of a 10-407 within 30 days after completion, abandonment, or suspension of a well and within 30 days after completion or plugging of a well branch, if occurring at a different time. Form 10-407 references the due date as “within 30 days of completion, suspension or abandonment”. 20 AAC 25.110(f) requires a separate Report of Sundry Well Operations (Form 10-404) not later than 30 days after any suspended well-site inspection. CPAI completed well work to suspend the well on July 23, 2023, with an AOGCC-witnessed plug verification inspection, establishing August 23, 2023, as the due date for the 10-407. Failure to submit a 10-407 within the required timeframe is a violation of AOGCC regulations. 1 Multilateral well, includes KRU 2F-18L1 (PTD 213-052), KRU 2F-18L1-01 (PTD 213-053), and KRU 2F-18L1- 02 (PTD 213-063) Docket Number: OTH-23-031 Notice of Violation December 5, 2023 Page 2 of 2 Within 14 days after receipt of this letter (next business day if the due date falls on a weekend or holiday), CPAI is requested to describe specific steps that have been or will be taken to prevent recurrence of this violation. The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at jim.regg@alaska.gov or (907) 793-1236. Sincerely, Jessie L. Chmielowski Commissioner ecc: Katherine O’Conner (Katherine.OConner@conocophillips.com) Greg Hobbs (Gregg.S.Hobbs@conocophillips.com) AOGCC Inspectors Phoebe Brooks Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.12.05 15:13:26 -09'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 121' 9-5/8" L-80 3161' 7" L-80 5923' 5" L-80 6436' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9. Ref Elevations: KB: 138' Sr Res EngSr Pet GeoSr Pet Eng 523' MD/ 523' TVD Oil-Bbl: Water-Bbl: 8535-8888' 14 bbl 15.8 Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 40# 121' 39' 9140' SUSPENDED Perforations: 9325-9335' MD and 6086-6095' TVD Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM 1296' FNL, 659' FEL, Sec. 4, T10N, R9E, UM SIZE DEPTH SET (MD) 8935' MD/ 5738' TVD PACKER SET (MD/TVD) 24" If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run):8979'3-1/2" 26# 9715' 39' 5739' 62.5# 1127' FNL, 693' FEL, Sec. 4, T10N, R9E, UM 50-029-22720-00-00 CASING WT. PER FT.GRADE 1/16/1997 CEMENTING RECORD 5942479 1650' MD/ 1525' TVD SETTING DEPTH TVD 5942310 TOP HOLE SIZE AMOUNT PULLED 518568 518603 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A Kuparuk River Field/ Kuparuk River Oil Pool KRU 2F-18 ADL0025666 18# 41' 8935' 5614'41' 41' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 6/15/2023 196-178/ 323-283 ALK 2587 12/22/1996 9715' MD/ 6385' TVD 8535' MD/ 5384' TVD P.O. Box 100360, Anchorage, AK 99510-0360 517519 5948608 CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 137 sx Class G6.125" TUBING RECORD 130 sx Class G8.5" BOTTOM 12.25" 28 sx AS I 41'330 sx ASLW, 1220 sx Class G w/60 sx AS I tail Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 4:29 pm, Nov 17, 2023 Suspended 6/15/2023 JSB RBDMS JSB 120523 GDSR-1/26/24 x Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1650' 1525' Top of Productive Interval 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: N/A - Suspended Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this documentLocation: Date: 2023.11.15 14:22:32-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled GLV, open pocket 2F-18 6/15/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 BAKER 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) 8,885.0 5,693.6 27.06 TUBING PUNCH 3' x 1.56" TUBING PUNCHER, 4 SPF, 3.4g HMX, 0.43" EH GEODY NAMICS TG39CM 2 N/A 5/29/2023 2.992 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,242.6 2,669.7 69.85 1 GAS LIFT OPEN 1 0.0 6/15/2023 0.000 6,783.6 3,855.2 36.58 2 GAS LIFT DV INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT GLV BK 1 1,352.0 9/18/2022 7:00 0.250 8,504.3 5,356.8 28.25 4 GAS LIFT OV BK 1 0.0 9/18/2022 8:00 0.250 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 MULTIPLE LATERALS, 2F-18, 11/15/2023 1:00:52 PM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 FRAC; 9,325.0 APERF; 9,325.0-9,335.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 11/15/2023 1:00:53 PM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 11/15/2023 1:00:53 PM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 11/15/2023 1:00:54 PM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 5/28/2023 OPTIMIZE WELL RAN STIFF 2.125" TOOLSTRING W/ 2.6" ROLLERS TO SIMULATE ELINE, TAGGED FILL @ 8883' SLM (8918' RKB). TAGGED 2.812" NIPPLE @ 488' SLM (523' RKB) 5/29/2023 OPTIMIZE WELL DISPLACE TUBING WITH SLICK DIESEL TO ~6500' MD WHILE RIH W/ TUBING PUNCHER. TAGGED FILL AT 8912' RKB. SHOOT HOLES IN TUBING FROM 8885' - 8888' RKB. U-TUBE FREEZE PROTECT WHILE POOH. JOB COMPLETE, READY FOR FULLBORE CEMENT PLUG 6/3/2023 OPTIMIZE WELL DISPLACE 360BBL 9.8 BRINE, 5BBL FRESH, 14 BBL 15.8 CEMENT, 2 BBL FRESH, WIPER BALL PUMPED DOWN WITH 74 BBL BRINE, SHUT IN RIGGED OUT 6/6/2023 OPTIMIZE WELL TAGGED CEMENT @ 8737' SLM & OBTAINED SAMPLE OF CEMENT. PERFORMED PASSING MITT TO 2500 PSI. READY FOR STATE WITNESS. 6/14/2023 OPTIMIZE WELL STATE WITNESSED (SEAN SULLIVAN) TAG CEMENT @ 8535' SLM. PERFORMED PASSING MITT TO 2500 PSI, ATTEMPT TO PULL GLV IN STATION 1 @ 4242' RKB, & STATION 2 @ 6783' RKB UNALBLE TO LOCATE WITH KOT IN BOTH MANDRELS , BRUSH GLV MANDRELS 1,2& 3. PUMP DIESEL DOWN IA, ESTABLISHED FLOW FROM IA TO TBG. JOB IN PROGRESS 6/15/2023 OPTIMIZE WELL PULL GLV FROM STATION 1 @ 4242' RKB, READY FOR DIESEL FREEZE PROTECT. 6/15/2023 OPTIMIZE WELL FREEZE PROTECT/U-TUBE PUMPED 86 BBLS DSL DOWN TBG TAKING RETURNS UP IA AND DOWN FL OF 2F-22 U-TUBE ( JOB COMPLETE ) 7/23/2023 OPTIMIZE WELL (SW) 2F-18 : State witnessed (Guy Cook) CMIT-T X IA Passed to 2760/2800 psi. 11/14/2023 ACQUIRE DATA (AC-EVAL) BLEED T X IA FOR BUR (COMPLETE) 2F-18 Suspend Summary of Operations MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2F-18 KUPARUK RIV UNIT 2F-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2023 2F-18 50-029-22720-00-00 196-178-0 N SPT 8951 1961780 2500 1850 2760 2710 2690 200 210 210 210 OTHER P Guy Cook 7/23/2023 CMIT-TxIA for well suspension per sundry 323-283. Testing completed with a Little Red Services pump truck and calibrated gauges. 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 2F-18 Inspection Date: Tubing OA Packer Depth 1790 2800 2750 2720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230722072712 BBL Pumped:0.9 BBL Returned:0.8 Tuesday, September 12, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 2LOSURGXFHU CMIT-TxIA for well suspension James B. Regg Digitally signed by James B. Regg Date: 2023.09.12 15:14:57 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:33 Township:11N Range:9E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:9715 ft MD Lease No.:ADL0025667 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 121 Feet Csg Cut@ Feet Surface:9 5/8''O.D. Shoe@ 5614 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 9142 Feet Csg Cut@ Feet Liner:5"O.D. Shoe@ 9715 Feet Csg Cut@ Feet Tubing:3 1/2 O.D. Tail@ 8979 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 8894 ft 8765 ft N/A Wireline tag Initial 15 min 30 min 45 min Result Tubing 2790 2770 2762 IA 1580 1580 1580 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Reservoir suspension for KRU 2F-18, 2F-18L1, 2F-18L1-01 and 2F-18L1-02. Tubing fill to 8894 ft MD. Tubing leaks at 8890 and 8908 ft MD. Tubing punched above fill for fullbore (T and IA) cement plug - top of cement planned for 8484 ft MD. Tagged top of cement deeper at 8765 ft MD. Passing Combo MIT TxIA to 2500 psi. CPAI to contact AOGCC before proceeding. June 14, 2023 Sully Sullivan Well Bore Plug & Abandonment KRU 2F-18 ConocoPhillips Alaska LLC PTD 1961780; Sundry 323-283 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2023-0614_Plug_Verification_KRU_2F-18_ss              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: Suspend Reservoir 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9715'9232' 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: Contact Email: Contact Phone: Authorized Title: 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 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Intervention Engineer Tubing Grade: Tubing MD (ft): 8935' MD and 5738' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 8979' 5/22/2023 Packer: Baker Liner Top Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025666 196-178 P.O. Box 100360, Anchorage, AK 99510 50-029-22720-00 ConocoPhillips Alaska, Inc. KRU 2F-18 Kuparuk River Oil PoolKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6385' 9715' 6385' None MD 121' 3161' 121' 5614' 5923'9142' 16" 9-5/8" 80' 5573' Perforation Depth MD (ft): 9325-9335' 9103' 5" 6086-6095' 9715'780' 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-283 By Kayla Junke at 3:58 pm, May 11, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O= ConocoPhillips, OU=Wells Group, E= katherine.oconnor@conocophillips.com, C= US Reason: I am the author of this document Location: Date: 2023.05.11 15:15:30-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor 10-407 SFD 5/17/2023 DSR-5/12/23 SFD -00 SFD , ADL0025667 SFD X Suspension is valid for 5 years from the date of the suspension approval(this 10-403). See AOGCC Industry Guidance Bulletin 21-002A for additional guidance. Well-site inspection is required within 12 months after this suspension approval VTL 5/23/2023 X GCW 05/23/23JLC 5/23/2023 5/23/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.23 16:37:31 -05'00' RBDMS JSB 052423 Date: 5 April 2023 Subject: 2F-18 Reservoir Abandonment Prepared by: Katherine O’Connor (214) 684-7400 Well History 2F-18 is a gas lifted producer that has TxIA communication. It had a patch installed from 8883’ – 8910’ RKB. The well stopped surfacing fluid after a scale squeeze on 12/6/22. Slickline went into tag and found fill in the whole above the patch. Coil did a FCO and cleaned ~17’ into the patch, but was kept tagging up on hard fill and were not able to make any further hole. Coil then pulled the upper section of the patch, then ran a venturi to clean out before pulling the lower section. Returns from the venturi showed sand and large chunks of rock. They attempted to pull the lower section of the patch, got temporarily detained, but were ultimately able to POOH with the lower section of the patch. They ran back in hole and made multiple attempts to clean out to TD but were unable to make any progress past 8894’ CTMD due to extremely hard fill (rocks). It is suspected the rocks are either coming from failed casing below the tubing or through one of the laterals. After coil rigged down, the well was circulated with ~11.5ppg brine to keep down the WHP. This well has high bottomhole pressure (4270 psi), TBGxIA communication, and because of the fill we are unable to get below the packer to secure the well with a plug. This wellbore it is currently being evaluated for either a RWO sidetrack or a full rotary capital sidetrack. The objective of this procedure is to place a balanced cement plug to secure the well for risk mitigation. Deviation Request: Abandon reservoir from top of fill @ 8894’ CTMD. Notes: x Current TIO pressure= 1525/1475/190. IA FL at surface x Two tubing leaks @ 8890’ and 8908’ RKB x Inclination Max: 71 deg @ 3950’ RKB x Min ID: 2.80” Camco landing nipple @ 8942’ RKB x Last SBHP 09/17/22 || 4270 psi || 8971’ RKB Calculations String Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3.5" tubing 0 8979 3.5" 9.3# 2.99" 0.0087 8884 77.2 115 tubing volume calculated from tag depth 3.5" x 7" annulus 0 8935 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 8884 234.6 38 casing volume calculated from tag depth s high bottomhole pressure (4270 psi), place a balanced cement plug t Procedure: Slickline 1. RIH with 5’ of 6 spf tubing punches and tag fill 2. PUH 10’ and shoot (expected depth ~8885’ MD) Pumping 1. RU cementers to pump down the tubing and take returns up the IA 2. Pump the following schedule: a. ±400 bbls 9.8 ppg brine b. 5 bbl FW spacer (ensure TBGxIA communication) c. 14 bbls cement d. 2 bbl FW Spacer e. 5” foam ball f. 74 bbls 9.8 ppg brine displacement Slickline & Fullbore 1. WOC for minimum 24 hours. Notify AOGCC inspector of cement timing and plug tag at least 24 hours in advance. 2. RU Slickline and PT equipment as required 3. RIH to tag TOC (AOGCC witness) @ approx. 8484’ RKB, record results 4. CMIT-TxIA to 2500 psi (AOGCC witness), record results Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled patch 2F-18 3/7/2023 praffer Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl 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 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 BAKER 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) 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,242.6 2,669.7 69.85 1 GAS LIFT GLV INT 1 1,304.0 9/19/2022 6:00 0.188 6,783.6 3,855.2 36.58 2 GAS LIFT DV INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT GLV BK 1 1,352.0 9/18/2022 7:00 0.250 8,504.3 5,356.8 28.25 4 GAS LIFT OV BK 1 0.0 9/18/2022 8:00 0.250 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 MULTIPLE LATERALS, 2F-18, 5/5/2023 11:54:11 AM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 APERF; 9,325.0-9,335.0 FRAC; 9,325.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 5/5/2023 11:54:11 AM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 5/5/2023 11:54:12 AM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 5/5/2023 11:54:13 AM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Anne Prysunka at 9:16 am, Oct 19, 2022 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ] Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ] Other Stimulate ] After Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ,] Re-enter Susp Well ❑ Other: Tubing Patch ❑� 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic ❑ Exploratory ❑ Service ❑ 196.178 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-029-22720-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0026666 KRU 2F-18 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field/ Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9715' feet Plugs measured None feet true vertical 6385' feet Junk measured 9232' feet Effective Depth measured 9174' feet Packer measured 8883', 89101,89351 feet true vertical 5952' feet true vertical 5692', 5716', 5738' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80, 16" 121' 121' Surface 5573' 9-5/81, 5614' 3161' Intermediate Production 9103' 7" 9142' 5923' Liner 780' 5" 9715' 8935' Perforation depth Measured depth 9325- 9335' feet True Vertical depth 6086-6095' feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8979' MD 5778' TVD Packers and SSSV (type, measured and true vertical depth) Packer: P21P Patch Packer 8883' MD 5692' TVD Packer: P2P Patch Packer 8910' MD 5716' TVD Packer: Baker Liner Top Packer 8935' MD 5738' TVD SSSV: Nipple WA N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-BbI Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 127 63 810 1355 164 Subsequent to operation: 1117 247 1 1592 1368 159 14. Attachments (required per 20 AAC 25,070, 25.071, 825.253) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil U Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: D' tC}" lA Sty D�emiy wan=a by Duary Freeborn ow.ou=wcw>=rrs, o=co�ecovnnup:.. Fr.eom, N/A nun,ry E=eo:ry neeboro@c000000nimp: Qom Authorized Name and Digital Freeborn 9eaon. 1 an,1he omho, amre 1«o—nt Lnw°°n-Eaa.e�.r Ake Contact Name: Dusty Freeborn Signature with Date: g oev:2ozz1o.1eolsa:az-0ear FmY PDF EdlDr Vanian: 11.2.1 Contact Email: dusty.freebornAconocoohillios.wm Authorized Title: Senior Well Integrity Specialist Contact Phone: (907) 659-7224 Sr Pet Eng: I Sr Pet Geo: I 1SrResEng: DSR-10119/22 Form 10-404 Revised 10/2021 RBDMS JSB 102822 Submit Within 30 days of Operations ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 18, 2022 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 217-18 (PTD 196-178). Please contact me at 659-7126 if you have any questions. Sincerely, 1j DN OU-AK MS, 0=L P Dusty DN:OWFKWE LL5,0=CanowPMIIpF E=e�elnrc tre outrVpwd Freeborn Leeson lxmlhe.—,c.k.Eam.nt om E 101 Riaer, pb¢ke Date: 20 iQ1B 09: W.16ll0V0' Eodt PDF Ealmr Wmion 11.2.1 Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. 2F-18 Tubing Patch Summary of Operations DTTMSTART JOBTYP SUMMARYOPS 8/27/2022 REPAIR WELL PERFORM LEAK DETECT LOG. LOG BASELINE PASS FROM SURFACE TO TOP OF PLUG. BEGIN PUMPING DOWN TBG WHILE TAKING RETURNS UP IA. PLUG AT 8931' RKB NOT HOLDING, IDENTIFY TBG LEAKS AT 8890' RKB AND 8908' RKB (ABOVE AND BELOW GLM STATION #5). PERFORM CALIPER LOG FROM 8925' RKB TO SURFACE. JOB COMPLETE, READY FOR PLAN FORWARD. 9/16/2022 REPAIR WELL PULLED SLIP STOP & 3 1/2" D&D PLUG @ 8931' RKB (MISSING ELEMENT). IN PROGRESS. 9/17/2022 REPAIR WELL DRIFT W/ 2.5" PUMP BAILER W/ 2.65" BOTTOM TO LINER TOP @ 8971' RKB (EMPTY); MEASURE BHP @ 8971' RKB (3997 PSI); BRUSH n' FLUSH PATCH INTERVAL FROM 8856'-8913' RKB; DRIFT W/ 27' X 2.72"OD DMY PATCH ASSEMBLY DOWN TO 8971' RKB (NO ANOMALIES); RAN 3 1/2" COLLAR STOP HOLEFINDER DOWN TO 8913' (LOWER SET DEPTH) AND OBTAIN GOOD TBG X IA TEST. IN PROGRESS. 9/18/2022 REPAIR WELL (RELAY USING 1.69" EDPU) SET LOWER 2.72" P2P (CPP35310) @ 8910.5 W/ MID ELEMENT @ 8913' RKB; RAN 3 1/2" TTS TEST TOOL & CMIT TBG X IA TO 2500 PSI (PASS); SET 2.72" P2P (CPP35319) SPACER PIPE, & ANCHOR LATCH (CPAL35160) @ 8883.5' W/ MID ELEMENT @ 8885.9' RKB (OBTAIN GOOD IA DDT). IN PROGRESS. 9/19/2022 REPAIR WELL SET 3 1/2" TTS TEST TOOL TO UPPER 2.72" P2P @ 8883' RKB & MITT TO 2500 PSI (PASS); CMIT TBG X IA TO 2500 PSI (PASS); REPLACED GLV'S @ 8504', 77681, 6783', & 4242' RKB (OBTAINED GOOD DDT AFTER SETTING EACH VALVE EXCEPT AFTER SETTING TOP STATION @ 4242' RKB. IN PROGRESS. 9/20/2022 REPAIR WELL PULLED GLV @ 4242' RKB, REDRESSED PACKING, & RESET @ SAME (OBTAIN GOOD IA DDT); MITT TO 2500 PSI (PASSED) & PULLED 3 1/2" TTS TEST TOOL @ 8883' RKB. JOB COMPLETE. 9/22/2022 ACQUIRE DATA (AC EVAL) RE-TIFL (PASS) v KUP PROD WELLNAME 2F-18 WELLBORE 2F-18 o;1Iljns Well Adributes Max AngleKMD 1" Alaska, Inc. Tom Name WNIbme APWWI Wellhore SlAue Icll°) K PAR K RIVER NIT 500292272000 PROD 0.96 MDIRKBI 3.950.00 AD MB1m IRKB) 9,T15.0 t-ewe Dento Comment R251ppm) Gate MmlNion End DataKBGNIRI RR OaIe OIM1er Ekv.. - SSSV: NIPPLE 50 2015 Last WO: 1I19I199J MULTIPLE IATERAUA2F-10, 18I12282262R25PM Last Tag S-, schematic A-U Anamatlon Depm NNR) 1 WNlbme patriots Laid Motl By Last Tag: SLM 9,'a.02F-,S 9I16I2019 'musum -� Last Rev Reason Anastatia. Wellmrt Entl Date Laid MM By Rev Reason: Pulled Plug, Set Patch, & Installed OLD 2F-18 9"u"U" zenoom, Notes: General & Safety An n na EDate st !ode' NOTE: ADDED LATERALS Li, L1-01 (OFF MAIN WELUBELLBORE), Li-02 SI18I2013 osfabgd CONDUCTOR: 41.p4C1 a 1 1 Casing Strings owing Descedm OD (in) IS (in) Top INNER set DeptM1 IN SO Depth._ ats-on(SENT Grace Top Caonmron CONDUCTOR 16 15,06 41.0 1210 121.0 62,50 H40 WELDED Cmung Gma,mi ma Or (in) ID (In) Top IRKB) set card, r.._ aM DepM._ Wini UIES) Gratle Top Cmnedlon SURFACE 95I8 8.83 41.0 5,614.4 3,161.5 40.00 LAO BTC 6ving co-r acn OD gn) ID (in) Top IRKS) SO Golan Us Set la,dan lWLn gNR) Grand Top Ccnnammn PRODUCTION ] 6.28 39.5 9141? 5,922.8 26.00 LAO BTC-MOD Caine E-minion OD (in) ID (in) Tap IflKB) Ed Gepth IS- Set Dappin WMUnIIWR) Oratle Top Coineilon GAS LIFT: 4.240.6 I1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 amng Den-dUian OD (in) ID (in) Top IflKB) $al NOR IN SO Daoth Wlhen (1WRl OrOE Top Cennedion LINER 5 4.28 8,935.4 9,715.0 18.00 LAG LTG -MOD Liner Details: excludes liner, pup, joints, casing, sub , shoe, float... rnPITVDI r0pmcl rvnminanD iop IRKB) (XKB) r) Xem Des Com Make Motlel (in) 8,935A S,T38.5 2T.0] PACKER BAKER TIEBACK SLEEVE WI LINER BAKER 4408 TOP PACKER SURFACE141.M.614.4- Tubing Strings: string max indicates LONGEST segment of string Top IRKB) set Earth... string Ma._ Tubing Coachman SucepIh IXKBI WI UWAL Gnae Top Conn«xon ID (in) 36.8 5,]]].8 3112 TUBING 8,9]9.4 9.30 L-80 EUE8RDMOD 2,99 GAS LIFT: e.]e3.e CC Details: excludes tubing, pup, space out, thread, RKB... OD Top TWO) Tap Intl Nominal Nominal Top IRMB) IRKS) P) Xem Des (In) Com Make MoMI ID (in) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 GAG LIFT: ],TG.] 523.0 522.E 5.80 NIPPLE 4.540 CAMEO DS IANDING NIPPLE CAMEO DS 2612 4,242.6 2.669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMEO KBMM 2.920 GAG JFT SSN.3 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2920 8,504.3 5,356.3 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 PACKER - PATCH- UPR: 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 e,W35 8,942.0 5,7444 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO CAMCO D 2.800 LEAK -TUBING', a.&N.b GO- MILLED TO 2.89" PRE-CTD ANCHOR LATCH ON GPACER me e.eers 8,949.1 5,T50.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 GAS DPT:eeEM.2 .,NO1.2 5.T52fi 2e80 SEAL All 1' 4.000 BAKER SEAL ASSEMBLY W11.52' BAKER 3.000 OF SEALS & MULE SHOE, (Mule LEAK -TUBING: B Sm.a Shoe) TTL ELMD @ 8972' SWS LDL 201199] °"cKER-PATCH e.8105 sol Other In Hole (Winaline retrievable plugs, valves, pumps, fish, etc.) Top ■ Top(UKBI IR BDI ToplacIE) De¢ Com Make Modal aN ID (in) 81883.5 5,692.3 27.11 PACKER- 2.72"UPPER P2P Val MID TTS Pap CPP35 1.625 PATCH -ORR ELEMENT @8885.9'RKB, 319 ■ SPACER PIPE, & ANCHOR LATCH (2].8' OAL) 9118/2022 8,MRS 5,695.8 26.97 ANCHOR 21116"P-110 SPACER PIPE& CPAL3 1.600 LATCH ON ANCHOR LATCH CONNECTED 5160 SPACER PIPE TO UPPER PACKER 8,890.0 5,698.0 26.88 LEAK -TUBING LEAK IDENTIFIED BY EL LDL AT 2.992 8899 RKB 8,908.0 5,714.1 26.76 LEAK -TUBING LEAK IDENTIFIED BY EL LDL AT 2.992 8908'RKB 8,910.5 5,716.4 26.84 PACKER- 2.72"LOWER P2P WI MID TTS P2P CPP35 1.625 PATCH -ONE ELEMENT@ 8913' RKB(4.01 310 GLorG: e.""Ho.Ts10- OAL) 911812022 PRODUCTION:... t41.J 9.ZC.0 6,003.4 2T.16 FISH LOST MILL AND GRAPPLE 9,268.0 6,035.4 2].19 WHIPSTOCK LATERAL WHIPSTOCK Mandrel Inserts : excludes pulled inserts st all FIGH:92320 Top (RKB) Top Rival (MEN Top In, I, on No Sam, Valve IahM1 TyI» Tyq OD (In) TRO Run (PSI, Run D. Com Make Modw pM Szprg 4,242.6 2,669.7 69.85 GAS LIFT GLV INT 1 1,304.0 9/19/2022 6.00 0.188 LLCU Din, laRmam 6,783.6 3,855.2 36,58 2 GAS LIFT DV INT 1 0.0 9I1812022 1130 0.000 we1W-L RR71 a10 Ts10 WHIPSTOCK. 92aa.g ],JfiB.] 4,709.2 28.69 3 GAS LIFT GLV BK 1 1,352.0 9I18I2022 7:00 0.250 uL1 v4an.W 92®o s,2eob $504.3 5,356.8 28,25 4GAS LIFT OV BK 1 0.09I1812022 8.00 0.250 8896.2 5,703.6 26,66 5 GAS LIFT EST RK 1112 00 712312022 3,00 0.000 DMY APERF',%st5.OB,3350 perforations In Slats RAC: 8.325.0 ' Shot TORKBO) Bt(RNS) Den¢ CMT Re9lner,Sa50.0 To RKB pI I man RKB ( I ( ) (RUNS) Onketl Zone Da IshWEang.0 Type Com cur PLUG: easl.O nKB 9325A 9335.0 6,086? 6,095.1 A5, 2F-18 N14I2010 6.0 APERF 2.5"HSD Gun, 60 tleg Dhase Stimulation Intervals IPERF', 9,3 9.08,3B3.0� Inter val Num Proppant Pmppant -Clean Wl Slmry Top (RKB) BIm IRKBI her Type Subtyps Skirt Dsb Deaynetl Nbl mail Nb) TOO(bM) TOO lbEg 9,325.0 9,335.0 1 FRAC 6I15I2010 0.0 0.00 0.00 LINER', SR354 OSQ v KUP PROD WELLNAME 2F-18 WELLBORE 2F-18L1 Gmoco3Ph'11'ps Well Attributes Max Angle 8 MD TD Alaska, Inc. FIeM Name WNIbore APW6lA WI Wellhore ue K PAR KRIVER NIT 22D2 PR D I,11.1 MBIM1KB) Z II1KB) 13,3060 lnm3yra Cammeni Ippm) Date M"I" ian En. BNe N... Ng RR Oaie O ner Ekv.. ••• 52S SSSV: NIPPLE 0 111=015 Last WO: 111911997 MULTIPLE IATERAL$2F-18L1, IM=0225: TO 29 PM I Last Tag VF—I-Iann,cla—IN Anmtallon Depih IRKBI WNlho,e End OAe 1 Lart Motl By Last Tag: SLM 2F-18L1 219I2013 I.Ba.11 Last Rev Reason AnnWatlon WellMrs End Date LIM MM By Rev Reason: FISH 21-1 AL1 I11212015 Ie6a I1 Notes: General & Safety An n Date IaslMM ey NOTE: ADDED LATERALS Li, L1-01 (OFF MAIN WELLBELLBORE), Li-02 SI18I2013 IcI .shod CONDUGTDN; at o-12, a Casing Strings css mg Deacrio- oD(in) ID (in) TuPInKBI Set Depth t sN Deplh._ WULen11Nrt) Graae rupcmnallun L1 Liner 2318 1.99 10,206.6 13,112.0 4.70 LRO ST-L Liner Details: excludes liner, pup, Joints, casing, sub , shoe, float... Topl1VD1 Top Inc' rvomma 10 rop lhNB) 1flN8) r) hem Des Com Make Motlel tin) 10,20fi.6 BILLET BAKER OH ANCHORED LINER BILLET Baker 1.nun GAS LIFT, d,N2.8 RR 218.3 DEPLOV I BAKER DEPLOYMENT SLEEEVE Baker Imix, perforations & Slots Shia TuP lTvo) BIm (Tvol D ena Tap (XKB) N. 111KB) (11KB) (rtKB) unkell zone Dale Ie Z0 Type Cam 1Q219.0 13,112.0 1 1 AA, 2E-18L1 5OwU13 1 32.0 I SLOTS SLOTTED LINER 6URFACE:01 Dfi.810.0— GAB LIFT, 8 ]e3.8 Gob LIFT: I.TEB.] GAB LIFT; B SD1.3 PPCKER- PATCH -UPR: B,SB3.5 LEAK -TUBING: 11.880.0 ANCHOR �ATCH ON SPACER PIPE: 8,86].5 GAS LIFT: B.BW.2 LEAK-TUBING;B,aWA PACKCR-PATCH-LWR: 0,910.5 e PRODUCTION, 38.59, 141.7 FISH; a2320 -I L1-01 NIal 5.2280.0 OBER,B,&15A9,]15.0 SWTS;06n20.10]510� L]91 u-r lahmam SLOTS;8611.0.12,522.0 L19z w.� e,sgB61z,s2zo sLors', m.ra.o-13.1u.o Lt UmN 10.2asa-13.1120 v KUP PROD WELLNAME 2F-18 WELLBORE 2F-18L1-01 Gxwlo;Ph'll'ps I Well Attributes I Max Angle 8 MD TD FIeN Name Wellhore APWWI Wellhore 6tAua Icl-) NO (M1KB) Act Bim IRKB) Alaska, Inc. K PAR KRIVER NIT 22272 1 PR D 1$5230 t-aeb, Comment K2S IPpm) Gate AnmiNlan End DateKBGNIXI RR Oate OIM1er Ekv.. - aaaMULTIPLELATERALB2F-TAL1L1, SSSV: NIPPLE 50 11122/2015 Las+WO: 1I19I199J 1011Z2T2252028PM Last Tag Xmmal athematic (ecWaX Annmtatlon DeWh IRKBI 1 Wellhore End OAe Lart End By Last Ta9:SLM 11-18L1-01 I sboll Last Rev Reason Amadatlon WeIIMrt Entlate D Laet EndBy Rev Reason: FISH 2F-18L1- 121212015 leballf 91 Notes: General 8 Safety Are atwe Ene Dale La¢iMM ar NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 SI18I2013 Osborl CONDUCTOR: 41.o-121.0 j Casing Strings sineacnn OD D9 (RKBI N St,etM1IXSDePh Uwd) Grane T,Cmnectlm loft 2318 9 &9]13 10]81.0 aJ0 L STCL1a-01gLDnfirrVt L mFin wellbote) Liner Details: excludes liner, pup, Joints, casing, sub , shoe , goat... I ToppvDt Top mal rvommeuD Top IXKB) (XXB) 19 Xem Oe¢ Co. Make MWE, lin) 8,9]1.3 DEPLOY BAKER DEPLOYMENT SLEEVE Baker 1.000 GAS LIFT: 4,2V.8 perforations 8 Slots SM1W In I—) Bim iTVDI Dena Tap IRKB) Bim (RKB) (RKB) IRS BID Ummd Zone Dale IeM1WaM) Type Cam 8,9820 10,]51.0 A4,21T-18LIAH 8I182013 I 320 I SLOTS SLOTTED LINER SURFACE; 41 UR.0100- GAB LIFT: 6,7M.8 GAS LIFT: 7.7E8.7 G4S LIFT: 8.5W.3 -UP PACKER - PATCHR: 3,BB E LE K-TUBING: SAWA ANCHOR LATCH ON SPACER PIPE: B.BB].5 GAS LIFT, SBW.] LEAK-TUBIN-:CAGCC PACKER-PATCH.DAR, 88165 is A PRODUCTION: 38.59, 141.7 F I6 X:9232.0 LINER', 8 GG PLO 715 0 L.1 NINDOW. 6.2011.0 8,2B0.0 L1KGUnm: 8.589 &125ZL0 'LOT'. B.BB2.0.10.]51.0 LT0H U. Iaflmeln wol W,e): 8.8]1.A10.]51.0 v KUP PROD WELLNAME 2F-18 WELLBORE 2F-18L1-02 Gxwlc@Ph'llips I Well Attributes I Max Angle 8 MD I TD FIeM Name WNIbme APWWI Wellhore 6lAua Icl°) N.L.KB) Ael IKB) Alaska, Inc. K PAR KRIVER NIT 22D2 2 PR D 1$50A0 r-, js,y Comment X36(ppm) DateMmiNian End Date KBGNIflI RR Daie OIM1er Ekv.. - •••MULTIPLELATERALOFF-1BLiL2, SSSV: NIPPLE 50 11122/2015 Lasi WO: 1I19I199J 1011212022520WPM Last Tag VxM1sl athematic (eMaB Amenatlon DmWh IRKBI 1 WNlhme Entl Dare 1 Lart End By La51Ta9:SLM 2F-18L1-02 2I9I2013 Dsbo11 Last Rev Reason Armad.1on "T"B" End Dare I Laet MM By Rev Reason: FISH 2F-18L1- 12I2I2015 le6allf 92 Notes: General & Safety A e align Ene Dale Laat Mae Br NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 S11812013 HC.N co.ouc]oR: at.o-ul.o Casing Strings Casing Deacrionn ODpn) ID(m) Top(IKE bet EW"Pfl... ."Dep1r WNen(IWR) Gentle TopGmnectlon L1-02 Liner 23)8 1.99 Q598.8 12522.0 Bm L-80 ST-L Liner Details: excludes liner, pup, joints, casing, sub , shoe , float... "JVD) Top In NummauD Top NUKE) (flKBI I°) Kem Des Com Make Maeel (in) APNS8 BILLET BAKER OH ANCHORED BILLET Baker 1.000 GAS LIFT; a,a26 Air, H.5 DEPLOY BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots shm Tup lrvDl B1mLrvDl Dena Top )flKBIF121- LINK.) (KKB)LinkedZone Dale )eMtsX) Type Cam 9,6110 A-0, 2F-18L1-02 W1A2B13 320 SLOTS SLOTTED LINER 6URFACE: 01 UG.810.0— G LIFT: e7eee .LIFT, ] ]Bd.] GAs LIFT; "ED PACKER-PATCH-UPR; 6.6B3.5 LEAK -TUBING: enEN0 ANCHOR LATCH ON SPACER PIPE 6,6BT.6 G4S LET B.6.2 LEJ K-TUBING:6SWA PACKER -PATCH .. 8,810.5 ■ PRODUCTION, 38,6 t<t] F I6X9`02.0 LINERB,WS.ii,]15.0 Oi01NINDOW... . 92&10 8WT6:BW2.0-10.7510 L.I.—r la1m.M we1Mn): 6.8i1.}10.]51.0 SLOTS; 91611.C-125Y1.0 Lt-0 L_r9eedr6125220 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-27_20237_KRU_2F-18_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20237 KRU 2F-18 50-029-22720-00 Caliper Survey w/ Log Data 27-Aug-22 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 PTD:196-178 T36947 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.30 12:34:41 -08'00' XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection.' /,~- / ~'/ File Number of Well History File PAGES TO DELETE RESCAN D Color items- Pages: n . Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA Diskettes, No.. Other, No/Type .OVERSIZED .Logs of vadous kinds n Other Complete cOMMENT~: Scanned by: E~,~.r~ TO RE-SCAN Notes: Re-Scanned by: ~,,er~ Mildred Damtha Nathan Lowell Date: /si STATE OF ALASKA ALI A OIL AND GAS CONSERVATION COMIIISION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r°®" Repair w ell {"'" Plug Perforations j✓' Perforate E Other j,T Set Plug After Casing E Rill Tubing E Stimulate - Frac I Waiver E Time Extension j'""` Change Approved Program EOperat. Shutdow n E Stimulate - Other E Re -enter Suspended Well '°- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ;i Exploratory E - 196 -178 3. Address: 6. API Number: Stratigraphic ]"`" Service E P. O. Box 100360, Anchorage, Alaska 99510 ` 50 029 - 22720 - 00 7. Property Designation (Lease Number): 8. Well Name and Number ADL 25666 . 2F - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): , none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9715 feet Plugs (measured) 9350 true vertical 6385 feet Junk (measured) None Effective Depth measured 9588 feet Packer (measured) 8935 true vertical 6270 feet (true vertical) 5739 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121' SURFACE 5573 9.625 5614 3161 PRODUCTION 9103 7 9142 5923 RECEIVED LINER 780 5 9715 6436 FEB 0 7 2013 Perforation depth: Measured depth: 9325'- 9335', 9359' -9383' AOGCC True Vertical Depth: 6086' -6095, 6117' -6138' NEt) APR 16 203, AOGCC Tubing (size, grade, MD, and TVD) 3.5, L -80, 8979 MD, 5778 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER TIEBACK SLEEVE W/ LINER TOP PACKER @ 8935 MD and 5739 TVD SSSV - CAMCO DS LANDING NIPPLE @ 523 MD and 523 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development I✓ ` Service E Stratigraphic E • 16. Well Status after work: ■ Oil I✓ Gas fa WDSPL E Daily Report of Well Operations XXX GSTOR E WINJ (°`° WAG I°°°°° GINJ r SUSP [ SPLUG ] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -427 Contact Dan Venhaus a 263 -4372 Email Dan.Venhaus @conocophillios.com Printed Name Dan Ve -us Title Staff CTD Engineer Signature A Phone: 263 -4372 Date -6-‘3 RBDMS FEB 14 20!A eS PI7 VfrF Form 10 -404 Revised 12/2012 4/124 ) - ubmit Original Only 2F -18 Well Work Summary DATE 'SUMMARY 11/25/2012 DRIFT TBG WITH 2.78" T, 3' STEM, 2.66" GAUGE RING TO D 11111PLE @ 8942' RKB. TAGGED @ 9320' SLM; MEASURED BHP ( 4326 psi ) @ 9335' RKB; SET 2.75" CA -2 PLUG @ 8942' RKB ( GOOD P.T. ) . SET CATCHER © 8935' RKB. IN PROGRESS. 11/26/2012 PULLED GLV's @ 8504' AND 7769' RKB. ATTEMPTED PULL GLV @ 6784' RKB AND APPEARS PULLED PART WAY OUT OF POCKET. RAN 2.61" LIB ON DE- CENTRALIZER AND CONFIRM VALVE BENT OUT INTO TBG. ATTEMPTED TO PULL W/ NO SUCCESS. IN PROGRESS. 11/27/2012 ATTEMPTED PULL BENT -LATCH GLV @ 6784' RKB WITHOUT SUCCESS. IN PROGRESS. 11/28/2012 ATTEMPTED PULL BENT LATCH GLV @ 6784' RKB WITH NO SUCCESS. IN PROGRESS. 11/29/2012 ATTEMPTED PULL BENT LATCH GLV @ 6784' RKB WITH NO SUCCESS. IN PROGRESS. 11/30/2012 ATTEMPTED PULL BENT LATCH GLV @ 6784' RKB WITH NO SUCCESS. IN PROGRESS. 12/1/2012 ATTEMPTED PULL BENT LATCH GLV @ 6784' RKB WITH NO SUCCESS. IN PROGRESS. 12/2/2012 WORKED WITH WEDGES / SPOONS TO STRAIGHTEN BENT LATCH GLV @ 6784' RKB. IN PROGRESS. 12/3/2012 ATTEMPTED STRAIGHTEN AND PULL BENT LATCH GLV © 6784' RKB. IN PROGRESS. 12/4/2012 ATTEMPTED PULL BENT LATCH GLV @ 6784' RKB WITH NO SUCCESS. IN PROGRESS. 12/5/2012 PULLED BENT LATCH GLV @ 6784' RKB. IN PROGRESS. 12/6/2012 PULLED GLV © 4243' RKB. SET DVs @ 8504', 7769', 4243' RKB. SET INTEGRAL LATCH DV @ 6784' RKB. ATTEMPTED PULL OV @ 8896' RKB. IN PROGRESS. 12/7/2012 PULLED OV @ 8896' RKB. LOADED TBG x IA WITH 310 BBL DSL. SET DV @ 8896' RKB. MIT IA 2500 _PSI, PASSED. PULLED CATCHER @ 8942' RKB. ATTEMPTED PULL CA -2 PRONG, SHEARED PULLING TOOL IN PROGRESS. 12/8/2012 ATTEMPTED PULL PRONG 8942' RKB & LEFT PRONG IN HOLE. LIB CONFIRMED PRONG DROPPED ON PLUG BODY. RECOVERED PRONG @ SAME. ATTEMPTED PULL PLUG BODY, UNABLE TO PASS GLM @ 8504' RKB. WORKED 2.66" LIB PAST OBSTRUCTION, PICTURE INCONCLUSIVE. IN PROGRESS. 12/9/2012 BRUSHED & FLUSHED GLM @ 8504' RKB. WORKED PULLING TOOL PAST OBSTRUCTION TWICE TO LATCH PLUG BODY, SHEARING TOOL. ENCOUNTERED OBSTRUCTION AGAIN ON 3RD ATTEMPT. LIB CONFIRMED BENT DV @ 8504' RKB. RAN LIB ON KOT AND OBTAINED PICTURE OF LATCH. IN PROGRESS. 12/11/2012 SET CATCHER @ 8942' RKB. PULLED BENT DV @ 8504' RKB AND REPLACED WITH NEW. MIT x IA 2500 PSI ( PASS) PULLED CATCHER & CA -2 PLUG @ 8942' RKB. READY FOR CTU. 1/9/2013 LOCATED 2.75" D- NIPPLE AT 8942' M.D. FLAG END OF PIPE AND CORRECTED DEPTH. TAGGED TOP OF FILL AT 9356' MD. WELL FREEZE PROTECETED. JOB IN PROGRESS. 1/10/2013 SET INFLATABLE CEMENT RETAINER AT 9 MD. PUMPED 1 OF 5 BBLS OF CEMENT THROUGH RETAINER. PRESSURED UP TO 4000 PSI. DUMPED THE BACK SIDE OF COIL. PRESSURED UP TO 4500 PSI. DUMPED COIL AGAIN AND PRESSURED UP TO 4500 PSI. UNABLE TO PUMP ANYMORE THROUGH RETAINER. UNSTUNG FROM RETAINER AND WASHED OUT REMAINING CEMENT. MAINTAINED 1:1 RETURNS. FREEZE PROTECTED WELL TO 2000' TVD. JOB COMPLETE. i KUP 0 2F -18 Co. oc i hills • s ° Well Attributes Max Angle & MD TD Alaska. InC Wellbore API /UWI Field Name Well Status Inc! (3 MD (ftKB) Act Btm (ftKB) L, «xx rnmaP, ': 500292272000 KUPAR UK RIVER UNIT PROD 70.96 3,950.00 9,715.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date Well Conan . - zF - e,1r23/2913617 z3AM - SSSV:NIPPLE 130 10/12/2007 Last WO: 1/19/1997 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ...End Date Last Tag: SLM 9,318.0 9/17/2012 Rev Reason: GLV C /O, Set CMT Retainer osborl 1/23/2013 mr Casing Strings HANGER, 37 Casing Description Stung 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd li CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (WD) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.835 41.0 5,614.4 3,161.4 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (WD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 38.5 9,141.7 5,922.8 26.00 L BTC - MOD ri Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (WD) ... String Wt... String ... String Top Thrd LINER 5 4.276 8,935.4 9,715.0 18.00 L -80 LTC -MOD Liner Details CONDUCTOR, Top Depth 41-121 (TVD) Top Intl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (In) NIPPLE, 523 � ' 8,935.4 5,738.5 26.79 PACKER BAKER TIEBACK SLEEVE w/ LINER TOP PACKER 4.408 8,949.3 5,750.9 26.80 HANGER BAKER LINER HANGER 4.408 ` 8,955.8 5,756.7 26.86 SBE BAKER SEAL BORE EXTENSTION 4.000 Tubing Strings III Tubing Description String 0 .. String ID ...Top (1168) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING I 31/2 I 2.992 I 36,8 I 8,979.4 I 5,777.8 9.30 L - 80 l EUE8RDMOD GAS LIFT. 4243 Completion Details Top Depth (TVD) Top Intl Nomi... Top (ftKB) MKS) ( °) Item Description Comment ID (In) 36.8 36.8 -0.16 HANGER FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.82 NIPPLE CAMCO DS LANDING NIPPLE 2.812 8,942.0 5,744.4 26.80 NIPPLE CAMCO D LANDING NIPPLE NO GO 2.750 8,949.1 5,750.7 26.80 LOCATOR BAKER GBH -22 LOCATOR 3.000 8,951.2 5,752.6 26.87 SEAL ASSY BAKER SEAL ASSEMBLY w/ 1.67 OF SEALS & MULE SHOE, (Mule 3.000 Shoe) TTL ELMD @ 8977 SWS LDL 2/7/1997 SURFACE, . _ p 41 -5,814 • • -r In Hole Uc•• _ - --.aaf 1TR: �F.r..- - :a• Top Depth �� (WD) Topinc GAS LIFT, ! • Top (ftKB) (ft (°) Description Comment Run Date ID (in) 6,784 9,350.0 6,108.6 27.08 CMT Retainer INFLATABLE CEMENT RETAINER SET, PUMPED JUST 1 1/10/2013 0.000 BBL CE/' NT \ ons & S / ---' Shot GAS LIFT Top (WD) Btm (TVD) Dens 7,]69 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 9,325.0 9,335.0 6,086.2 6,095.2 A -5, 2F -18 6/14/2010 6.0 APERF 2.5" HSD Gun, 60 deg phase 9,359.0 9,383.0 6,116.6 6,137.9 A -4, 2F -18 2/11/1997 4.0 IPERF 2.5" HSD; 180 deg phasing ill Stimulations & Treatments Bottom GAS LIFT. Min Top Max Btm Top Depth Depth 8,504 Depth Depth (TVD) (TVD) IS (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment IR 9,325.0 9,335.0 6,086.2 6,095.2 FRAC 6/15/2010 A -SAND FRAC - placed 95,972 Ibs. of 16/20 Carbolite behind Perfs @ 9325-9335' El Notes: General & Safety GAS LIFT, S End Date Annotation 8 89 10/14/2010 NOTE: View Schematic w/ Alaska Schematic9.0 ER I. NIPPLE, 8,942 *0 LOCATOR. 8,949 t ('! SEAL ASS 8,951 11 PRODUCTION. • 39 -9,142 APERF. 9,325.9,335 FRAC, 9,325 Mandrel Details Top Depth Top Port CMT Retainer, ] (WD) Intl OD Valve Latch Size TRO Run 9,350 N... Top(ftKB) (ftKB) (1 Make Model (In) Sery Typo Type (In) (psi) Run Date Com... CMT PLUG, 1 4,242.6 2,669.7 69.85 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/6/2012 6:00 9,351 2 6,783.6 3,855.2 36.58 CAMCO KBMM 1 GAS LIFT DMY INT 0.000 0.0 12/6/2012 11:30 IPERF. 3 7,768.7 4,709.1 28.59 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/62012 7:00 9,3599.383 4 8,504.3 5,356.8 28.60 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/112012 8:00 5 8,896.2 5,703.6 26.66 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 12/7/2012 3:00 I I LINER, 8,935 -9,715 TD (2F -18), 9.715 (0 -4,1# I �� 6, THE STATE Alaska Oil and Gas � °f Conservation Commission __ ALAS GOVERNOR SEAN PARNELL 333 West Seventh Avenue ro. Anchorage, Alaska 99501 -3572 ALAS' Main: 907.279.1433 Fax: 907.276.7542 Dan Venhaus SCANNED JAN 2 $ 2013 Staff CTD Engineer ConocoPhillips Alaska, Inc. ,- 6 — t 1 g P.O. Box 100360 1 b Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F -18 Sundry Number: 312 -427 Dear Mr. Venhaus: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this of of November, 2012. Encl. • STATE OF kL A�A OIL AND GAS CONSERVATION COM ION likikAV APPLICATION FOR SUNDRY APPROVALS x�' 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r rforate New Pool r Repair w ell r Change Approved Program r • Suspend r Plug Perforations •1 vPerforate r Rill Tubing r lime Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing Other:Set Plug r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development jp" Exploratory r 196 -178 3. Address: Stratgraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22720 -00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No Jy 2F -18 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25657 Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9715 6436 7822' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' SURFACE 5573 9.625" 5614' 3125' PRODUCTION 9103 7 9142' 5874' RECEIVED LINER 780 5" 9715' 6436' NOV ( ° 201 AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9325' 9335', 9359' - 9383' 6035' 6044', 6065' - 6086' 3.5 L - 80 8979 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER LINER TOP PACKER MD =8935 TVD =5637 SSSV - CAMCO DS NIPPLE MD =523 TVD =523 i1 12. Attachments: Description Summary of Proposal ji 13. Well Class after proposed work: Detailed Operations Program BOP Sketch " Exploratory r Stratigraphic r Development 17 . Service 1 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/19/2012 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r i GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Venhaus © 263 -4372 Email: Dan .Venhausetconocophillios.com Printed Name n Venh Title: Staff CTD Engineer Signature - Phone: 263 -4372 Date i /-4, ••-• 1 ?— Commission Use Only Sundry Number:�j1 ' � I Lf 1 Conditions of approval: Notify Commission so that a representative may witness ✓✓ 11 C `— Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No 4 Subsequent Form Required: / . -/d / n APPROVED BY Approved by: / / 9,-61,24-s--- THE COMMISSION Date: /Ns — /2- Approved application is valid for 12 months from the date of a proval. 0 RI e ) �/ fL ReDms KY 16 i t mit Form and Attachme is in Duplicate R` • • KRU 2F -18 Summary for Plugging Sundry (10 -403) Summary of Operations: Well KRU 2F -18 is an A -sand producer that has been shut in for several months due to problems with sand production from casing damage in proximity of the A4 -sand perforations. A recent attempt to isolate the A4 perforations with an inflatable bridge plug . and produce the A5 perforations was unsuccessful when the plug was blown up hole and lodged in the tubing. The plug has been recovered and this second attempt will incorporate an inflatable cement retainer and cement squeeze of the A4. Returning this well to production will also benefit pressure reduction in the southern 2F /2G area where several CTD sidetracks are scheduled in 2013. /07/e A4 Perforation Isolation Operations 1. MIRU slickline. Dummy all GLMs. Perform MIT -IA. Obtain SBHP 2. MIRU service CTU. Set cement retainer in 5" production liner @ 9350' MD, between A4 perforations (9359' — 9383' MD) and A5 perforations (9325' — 9335' MD). 3. Squeeze approximately 3-4 bbl of 15.8 ppg cement through retainer into A4 perforations. 4. RD CTU. Wait 72 hrs. 5. Install GLV design and return well to production. Page 1 of 2 November 6, 2012 110 , KUP • 2F-18 Conoccif;hillips Oi _ Well Attributes Max Angle & MD t TD Wei lbort ARE A UWI FA Name Well Status Inc' il MD (WM Jae tr.-■ etKBI alatbeet ii 5 00292272000 KUPARUK RNER UNIT PROD 71 "0 1.93531 9 7" 5.0 Gosieboillietilso a ' ''' Comment r2S teem) Date Annotation Eno Date KB-Grd (ft) Rig Release Date ... SSSV: NIPPLE 130 10)1212007 Lest WC: 1;' 911997 . _./88 - or." • .strentett. a:1,3i Atamtation Depth MKS) 6n4 Date Armotation Last Mod ... End Date Lazt Tag SUM 9 318.0 3 Rev Renoir MANDREL LATCH ORIENTATION nlren- 10;312312 , (( pip Casing Strings Casing Description Swing 0.. String 0... Top I fti(El se Depth if_ Set Deign (TVD).. String Wt.. String .. String Top Thrd C.1,_49DUCTOR 16 15.062 4'0 121.3 121.0 62.52 H WELDED gaunt' Description String 0... String ID ... Top MKS) See Depth if... Set Depth (WO)... String Wt.. Swing ... String Top Thrd SURFACE 9519 8.335 41.0 5,614 4 3,125.0 40.00 L OTC Casing Description Swing 0 String 111 ... Top ift613) Set Depth 0... Set Depth ;TIM)... String Wt._ String . String Top Thrd PRODUCT1CN 7 6.276 38.5 9141.7 5873.9 26.00 L OTC Casing Description String 0_ String ID ... Top (5KS) 'Set Depth (f... Set Depth (TV'S)... String Wt.. String ... String Top Thrd LINER 5 4.276 0,9354 , 97'50 1320 -30 LTC-MOD _,....... Liner Details CONDLICTOM. Top Depth ot.i2t ITVD) Top Tool Monti . lit Top (9968) (9tt0S) 0) Item Description Comment 0 brit A .131.0, 523 4 i.i., 8 935 4 5 606 9 26 96 PACKER BAKER TIEBACK SLEEVE w; LINER1CP PACKER 4.420 89493 399393 26.53 HAWIEr( BAKER LINER HANGER 4.420 • 1 I 6 95,5 8 5707'' 26 92 BE Tubing Strings BAKER SEAL BORE EX AN5 . CI 4.330 Tubing Description I String 0. 'String ID .1Top ;pit El I Set Depth if . 1Sol Dept, "VD) 1Stri Wt. . I 911190 IStrmg Top Thrd 1 I 31.2 2.332 36.3 8 979 4 5'26.1 ax, 1 ...-60 EU EhR DMOD o021.T ' -4 Completion Details . 1 Top Depth (WO) Top Intl Heani.. M ill° Top MKS) ( r) Item Description Comment d) 0n) 368 368 000 RANGER RAC. GEIN IV TU2ING HANGER 3.503 . . . .. : :: • - ( :. . .. - : ::. - - ' 523 V 5228 5 JO NI-1-16 1 -AMLU )S LANLANC1;4 24 li - . .. . .. _. - :%':4 6 942 0 5 692 8 26 95 NIPPLE CAMCO 0 LANDNG NIPPLE NO GO 2.750 6 949 1 5.6991 26.93 LOCATOR BAKER 253H-22 LOCATOR 3.000 1 6 951 2 5 701 0 26.93 SEAL ASSY BAKER SEAL ASSEMBLY w.; 1.62' OF SEALS & MULE SHOE. (F481^. 3.000 Shoe) - n_ ELMO (5 8972' SWS LDL 21741557 1 c - .:175 : i': 4 Other In Hole ireline retrievable plugs, valves. pumps, fish, etc.) Top Dept (rum Top Incl . ..„ , GA:: t lc. Top 119613) (hrtEl( (e) 0..„,,,,,r, Comment Run Date ID lin( 7.320 4.702.7 28 68 OVERSHOT BAITED OVERSHOT (3 5 " BAITSUB wi 2.31' RN 00 wl 5102312 1.375 1.375 F & 2.67 BELLGUIDE se/ 1 314 RN, 0AL.3 1.421 1.764 3 25 84 HLUG :NI-LAI ABLE BRIOGE PL:,..(9 0.'0(2312 •2.002 r - Perforations & Slots 044.76-; ,. : Shea Top ITVD) Btel (9YD) Dens IR Top (ttlitEl) 890 (9998) 1106EI1 MKS) Zone Date MS- Type Comment NM 9 325 9.335 5034.8 3 34.1.7 4-5, 2F-1 d 61142010 3.0 APERF 2.5' HSO am. 60 dey ;Awe 9 335 9.232 6 065 0 5 085 4 :. 2F- 2 4.0 PERE 2.5' HSO 180 veg phacing overtenL i' 1! Stimulations & Treatments .L,c. 7 .322 Pottorn Min Top Max atm Top Dope, Depth Depth Depth 1100) MT) IMO) 9ttKI3) i915581 (f Typo On! torment OM LW 325.0 9.335.0 6.534 8 6.043 .7 BRA:- 618)2010 A. eRS.L. - plat ed 95 972165. co 16,2e a 504 :;'' Carbolte behind PetN, (11 3325-5335' liff Notes: General & Safety End Date A,notation 1.2 : 200 I '40 Vtee. Schematic A. :Aha Scheme 0 : (31K G.47 LW' ..; C' , .. 3 091 Overshot and IBP have arig been recovered ra Sill it .010. 0342 1 1..... 14 DCATOR.. EN a , 34a 31/41 933' 0501 Proposed retainer 1 , set depth 9350' RKB (9342' ELM) -D.Tzt , drel Details A5 (TVDt Top Depth Top Inc OD Port gal. Latch Sim TRO Ron Stn Tap MOM (5KS) ri (9ato mode iin) 5., Type Type 1001 i.Poii 6.0 0010 Cent_ 1 4,242.6 2.647.2 70.55 0.01400 KBMM 1 GAS LIFT GLV BK 0.156 1.3490 523 6:00 -simaimuitammatimmunlikilLIIIIIIMINIERIPi ' 011 .i• s. 159-30 '11111EMINIUMISigliiiiiiMIMIMIN1112=1611111111111112111''''' " ''" . ' IlliaiNETMEggilaliniNgilll' 1111112=111=1:1111111111111219 °. 2 " "": C 5 8."'1 MIISIMIIMMI ''''''' Kg GAS LIFT WM IT ma 00E; 12010 3:1' A 1 4_ 41 1 shi T ■ Page 2 of 2 November 6, 2012 zCz • 3 - WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Bottom Hole Presure Survey: 2F -18 Run Date: 9/19/2012 1 listed submitted herewith. Please address any problems or The technical data sted b elow is being YP concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -18 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22720 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 22720 -00 SCANNED FEB 2 7 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com '1;1 / V/_ Date: > \ O / \ /,- Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2F-18 Run Date: 6/14/2010 July 16, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F-18 Digital Data in LAS format, Digital Log Image file 50-029-22720-00 ~{ ~t ~~~P: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto r ~~ 4 Date: _ ~ '~ . ~~ e t~~3~ Signed: STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS t Operations Performed: Abandon ~"" Repair w ell Plu Perforations ~ f -° Other ("" g ~ Stimulate ~ Alter Casing ~ Pull Tubing ~ Perforate New Pbol °" Waiver `°` Time Extension """ Change Approved Program ~""" Operat. Shutdow n r Perforate ~~ Re-enter Suspended Well J" 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ~'" 196-178 3. Address: Stratigraphic ~ Service ~~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22720-00 7. Property Designation: 8. Well Name and Number: ADL 25666 2F-18 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9715 feet Plugs (measured) 9352 true vertical 6385 feet Junk (measured) None Effective Depth measured 9343 feet Packer (measured) none true vertical 6051 feet (true vertucaq none Casing Length Size MD ND Burst Collapse CONDUCTOR 121 16 121 121' SURFACE 5615 9.625 5615 3125 PRODUCTION 9140 7 9140 5872 LINER 780 5 9715 6385 ;t~~~~, Perforation depth: Measured depth: 9325'-9335',( 9359'-9383' -plugged) ~ ;~~'' `~~'~ - ~,., b ~r ~'. ~ ~, ,, True Vertical Depth: 6035'-6044', (6065'-6086' -plugged) 4~~'"' ~~~~~~ f~D Tubing (size, grade, MD, and TVD) 3.5, L-80, 8979 MD, 5726 TVD .,ll~~ ~ ~. 20~~ Packers & SSSV (type, MD, and TVD) none ~~88k8 ~ ~(~a1~ C~° [;OrrHrIISSIOft Camco'DS' nipple @ 523' MD, 523' TVD Nora e 11. Stimulation or cement squeeze summary: Intervals treated (measured): 9325'-9335' MD Treatment descriptions including volumes used and final pressure: 95,972 # of 16/20 carbolite behind perfs 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation 57 960 513 -- 153 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service 15. Well Status after work: Oil ~, Gas ~°°` WDSPL Daily Report of Well Operations XXX GSTOR C"' WAG ~'"" GASINJ "` WINJ ~°` SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Howard Gober t~ 263-4220 Printed Name Howard Gober Title Wells Engineer Signature Phone: 263-4220 Date ~~~~J~ RBDMS JUL 13 101 -T ~~ ..to Form 10-404 Revised 7/2009 Submit Original Only 2F-18 Well Events Summary • DATE SUMMARY 5/13/10 DRIFTED 11' 2.55" DUMMY GUN WITH 2.735" GAUGE RING TO 9320' SLM. PULLED 1.5" DV FROM 8896' RKB**OPEN POCKET*" READY TO LOAD IA. IN PROGRESS 5/14/10 SET 2.75" CA-2 PLUG Cad 8942' RKB. BLED GAS FROM IA WHILE ATTEMPTING TO CIRCULATE AND PRESSURED TBG UP, SUSPECT ICE PLUG IN IA. PUMPED 20 BBL'S MEOH DOWN IA. IN PROGRESS 5/15/10 DHD SHOT F/L @ 2190'. PRESSURED IA TO 3000# WITH 55 BBL'S MEOH. ATTEMPT TO PULL A-2 PRONG TAGGED 8' HIGH. BLEED TBG AND IA STARTED TO TRACK LRS PUMPED ADDITIONAL 7 BBL'S MEOH NOW CAN SEE TBG AND IA TRACKING ICE PLUG APPEARS TO BE FREEING UP. IN PROGRESS. 5/16/10 UNABLE TO CIRCULATE T X IA. APPARENT SAND BRIDGE IN IA BETWEEN GLM @ 8504' AND 8896' RKB. TAGGED FILL IN TBG @ 8728' SLM. PULLED 1" DV FROM 8504' AND ABLE TO PUMP DOWN TBG TO ESTABLISH COMMUNICATION WITH IA. SET 1" BTM LATCH DV @ 8504' RKB. READY FOR COIL. 5/22/10 TAG SAND IN TBG @ 8748' CTMD. CLEAN OUT SAND W/ DIESEL & DIESEL GEL TO CA2 PLUG @ 8942' RKB. PUMP 40 BBLS OF DIESEL DOWN IA TO CONFIRM COMMUNICATION THROUGH OPEN POCKET @ 8896' RKB. MADE A FINAL CLEAN OUT SWEEP TO PLUG AFTER CIRCULATING THROUGH MANDREL. WELL IS F/P WITH DIESEL. READY FOR SLICKLINE. 6/10/10 PULL 2.75" CA-2 PLUG @ 8942' RKB. IN PROGRESS. 6/11/10 PUMP 200 BBLS DIESEL DOWN IA, SET 1.5" DV @ 8896' RKB. MIT IA ""PASS**. DRIFT TBG 2.73" TO TAG COLLAPSED LINER @ 9368' RKB. 6/12/10 SET 2.5" IBP 9352' FOR PRE-FRAC WORK: COULD NOT PULL OFF OF IBP. PULLED OUT OF WP, LEFT ENTIRE TOOL STRING IN HOLE AT IBP SET DEPTH TO BE FISHED AT A LATER DATE. 6/13/10 FISHED ELINE TOOLSTRING f/SET BAKER 2.5"IBP. 3000# MITT PASSED. PLACED 6 GALLONS OF 15.8 PPG CLASS "G" CEMENT ON TOP OF BAKER 2.5" IBP @ 9346' RKB. IN PROGRESS 6/14/10 TAGGED TOC @ 9308' SLM (=9343' RKB) DRIFTED TREE FOR TREESAVER WITH 2.90" GAUGERING 6/14/10 PERFORATE A5-SAND@9325-9335 WITH 2.5" 6SPF 60DEG PHASING HSC. 6/15/10 SCREENED OUT WITH TUBING FULL OF 8 PPA OF 16/20 CARBOLITE AND XL GEL. PUMPED A TOTAL OF 118639 LBS OF PROPANT PLACING 95972 LBS INTO THE FORMATION. FRAC PUMPED TO 46% OF DESIGN. 6/17/10 TAG FRAC SAND IN TBG @ 182' CTMD. CLEAN OUT FRAC SAND TO 6200' CTMD W/ SEAWATER & BIO ZAN. HAD LARGE AMOUNT OF FRAC SAND IN RETURNS. RACK BACK FOR THE NIGHT, IN PROGRESS. 6/18/10 TAG FRAC SAND IN THE TBG @ 8345' CTMD. CLEAN DOWN TO IBP @ 9352' RKB W/ SEAWATER & BIO SWEEPS. MADE 3 SWEEPS IN 5" LINER, SLOWED DOWN FOR ALL JEWELERY. GOOD SAND RETURNS ALL DAY. FREEZE PROTECT TBG FROM 3600' TO SURFACE. WELL READY FOR SLICKLINE. 6/21/10 TAG @ 9315' SLM, EST. 9325' RKB. PULLED DV @ 8896' RKB. IN PROGRESS. 6/22/10 SET OV @ 8896' RKB. PULLED DVs @ 8504', 7769', 6784' & 4243' RKB. SET GLVs @ 8504', 7769' & 6784' RKB. IN PROGRESS. 6/23/10 SET GLV @ 4243' RKB. READY FOR FLOWBACK OPERATIONS. ~~i ~.G)11+C}~t7~1 i (~ t X15 ';OVnUCIUR NIPPLE, 523- GAS LIFT,_._ _._.. 4,243 SURFACE. 5,615 GAS LIFT, _ _- s.7e4 GAS LIFT, 7.769 KUP ~ 2F-18 WeII Attribut e s IMax Angle 8r MD TD ',Welllwre API/UWI _ _ Field Name Well Status ~,Incl (°) MD (kKB) Act Btm (kKe) I ( 500292272000 ~KUPARUK RIVER UNIT PROD 71.10 3,995.34 9,715.0 Comment 'M2S (ppm) ', Date ~IAnnotat~on Entl Date KB-Grd (k) Rig Release Dafe -_.. _ SSSV: NIPPLE 130 10/12/2007 Last WO: I 1/19/1997 Annotation i End Date Depth (kK8) Annotation Last Mod By iEnd Date Last Tag: SLM t I 8,728.0 5/15/2010 Rev Reason: PERF /FRAC ~ Imosbor 6/16/2010 Casin Strin s _ _ String OD ~ String ID Set Depth Set Depth (ND) i String WI String i Casing Description (i) IiN ~n ~ ~ Top (kKe) (kK6 ) ftK6) ~ l (Ibs/ft I Grade Strin To Thrd 9 P CONDUCTOR 16 15.062 0.0 121.0 121.0 62.50 H-00 SURFACE 95/51 8.697 0.0 5,615.0 3,125.2 40.00 L-80 Inc 4,243 2,647.3 70.55 GAS LIFT CAMC0IKBMM/1/DMYlBK/// Comment: STA 1 8/9/ZOOS 6,784 3,807.2 3237 GAS LIFT CAMCO/KBMM/1lDMYlBK/I/ Comment: STA 2 8/9!2008 7,769 4,658.0 28 77 GAS LIFT CAMCO/KBMM/7/DMYIBK/// Comment: STA 3 8/9/2008 8,504 5,304.8 28.15 GAS LIFT CAMCO/KBMM/1/DMYBTM//i Comment: STA4 5/16/2010 8,896 5,651.8 27.OSi GAS LIFT CAMCO/KBMM/1/DMY/BK!//Comment STAS 6/11/2010 8,942 5,6928 26.951 NIPPLE Camco'D'Nipple NO GO 1/16/1997 8 949 5,699.0 26 93 PBR Baker'GBH-22' LSA PBR 1 /1 611 9 9 7 8,9791 5,725.8', 26.87 TTL (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 1/16/1997 Btm (TVD) (kKB) i Zont 6,043.7A-0, 2F-18 180 deg phasing GAS LIFT, _-.. _ 8,504 GAS LIFT,- _...._. 8,696 NIPPLE, 8,542- PBR, 8,949 TTL. 8,979 - PRODUCTION. -_ 9,140 APERF, 9,325-9,335 ~_ fRAC. 9.325 PLUG. 9 352 (PERF, _-_. 9,355-9,383 LINER. 9,715 9,715 Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) (ftK8) (kKB) ~, (kKB) (kKB) Type Date li Comment 9,325.0 9,3350 6 034.8 G.043.7~FRAC 6 /1 5120 1 0 A-SAND FRAC -placed 95,9721bs. of 16/20 Carbolite behind Perfs @ 9325'-9335' • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2F-18 Run Date: 6/12/2010 June 25, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F-18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22720-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr g Date: _'~'~ !~ z'I=i~i ~,~},~6 i~ ~~3~ Signed: • ~. :° ~ 'i i ~onocoPhi I ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • I~~~~\g ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped October 16, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, . ` ~ r ~~~~ 2Q08 MJ Lov~ and ^, ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Datp 10/22/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2F-02 183-188 20" NA 20" NA 2.21 10/16/2008 2F-03 183-187 20" NA 20" NA 2.23 10/16/2008 2F-05X 196-203 7" NA 7" NA 1.7 10/16/2008 2F-06 184-019 18" NA 18" NA 1.72 10/16/2008 2F-11 184-041 .20" NA 20" NA 2.22 10/16/2008 2F-13 183-156 12" NA 12" NA 6.8 10/16/2008 2F-14 183-159 7" NA 7" NA 4.25 10/16/2008 2F-18 196-178 5" NA 5" NA 11.9 10/16/2008 2F-19 196-201 6" NA 6" NA 1.7 10/16/2008 ON OR. BEFORE PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 01/21/99 RUN RECVD 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 96-178 CN/LDT .L-~9140-9706 LDT/CNTG/SGTL -~-9140-9706 7612 ~SCHLU~ LDT/C~L CBL ~800-9575 DGR/RES-MD ~5605-9716 DSR/C~O/SLD-MD ~L~.605-9591 DSR/RES-TVD ~3130-~385 DGR/CNO/SLD-TVD ~3121-6079 ,PBt~. 7972 7973 DIR SRVY FINAL FINAL 1 PB1 FINAL FINAL FINAL FINAL FINAL FINAL FINAL SPERRY MPT/GR/RES/CNP/SLD/ROP 3-6 ~D/SpERRY MPT/GR/RES/CNP/SLD/ROP 3 ~BH 5700-9715 02/14/97 02/14/97 02/14/97 03/05/97 03/05/97 03/14/97 04/23/97 04/23/97 04/23/97 04/23/97 04/23/97 04/23/97 04/30/97 04/30/97 05/20/97 10-407 K~COMPLETION DATE ~/~/~/ DAILY WELL OPS R '~.~/ TO dry ditch samples required? ~. no Are And received? Was the well cored? yes ~~i~nalysis & description received? Are well tests required? es :~o Received? ~~ Well is in compliance ~ Ini'~ial COMMENTS yes ~ STATE OF ALASKA AL -,_,,A OIL AND GAS CONSERVATION COMMIS¢,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1127' FNL, 693' FEL, Sec. 4, T10N, R9E, UM At effective depth 1242' FNL, 670' FEL, Sec. 4, T10N, R9E, UM At total depth 1296' FNL, 659' FEL, Sec. 4, T10N, R9E, UM 6. Datum elevation (DF or KB) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-18 9. Permit number/approval number 96-178 10. APl number 50-029-22720-00 11. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured true vertical 9715 6385 Effective depth: measured 9 5 8 8 true vertical 6270 feet Plugs (measured) None feet feet Junk (measured) None feet ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 5573' 9101' 780' measured 9359'-9383' true vertical 6065'-6086' Size 16" 9-5/8" i, Cemented Measured depth 280 Sx AS I 121 ' 330 Sx ASLW & 5 61 4' 1220 Sx Class G w/60 Sx AS I tail 130 Sx Class G 91 4 0' 137 Sx Class G 9 71 5' True vertical depth 121' 3125' 5870' 6385' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 8979' Packers and SSSV (type and measured depth) Packer: Baker GBH-22 Locator @ 8951'; SSSV: None, nipple @ 523' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 10/5/97. Intervals treated (measured) 9359'-9383' Treatment description including volumes used and final pressure Pumped 280.1 Mlbs of 16/20 and 12/18 ceramic proppant into formation, fp was 7200 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure RECEIVED Alaska 0il & Gas Cons, C0mmlssJ0.fi Anchorage Prior to well operation 0 0 0 915 144 Subsequent to operation 1094 9 8 9 107 924 154 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed(////;~.~,~,,~// ,,~/~~ Title Wells Superintendent Form 10,--"'¢4'(~-4 ~r[~v-.,d"6/l~5/~8~ " / Date ~_----~-~_~' J_~;~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. -- KUPARUK RIVER UNIT '~, WELL SERVICE REPORT ~ K1(2F-18(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-18 FRAC, FRAC SUPPORT 0926971201.3 DATE DAILY WORK UNIT NUMBER 10/05/97 PUMP 'A' SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes (') ~oI ® Yes i~) No DS-YOKUM JOHNS /~ FIELD A F C# C C~ DAILY COST AC CUM COST eSr~(l~-er An~~n ESTIMATE KD1676 230DS28FL $167,804 $182,173 . Initial Tb.q Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Out I · 500 PSI 1100 PSI 50 PSI 500 PSII 250 PSII 500 PSI DALLY SUMMARY PUMPED 'A' SANDS REFRAC WITH 280,078 # UP TO 12/18 14.4 PPA PROPPANT TO PERFS, LEFT 6718# 12/18 PROPPANT IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LR-I-LE RED PUMP AND APC VAC TRUCK. 08:22 HELD SAFETY MEETING 08:45 INITIAL WHP 500 PSI. PUMP BREAKDOWN, SCOUR AND FLUSH. AT 25 BPM TO 15 BPM AND 4587 PSI. PUMP 5879# OF 16/20 PROPPANT IN SCOUR STAGE. SHUT DOWN FOR ISIP 1726 PSI. 09:49 PUMP DATA FRAC AND FLUSH AT 5 TO 15 BPM AND 4756 PSI. SHUT DOWN FOR ISIP 1969 PSI AND CLOSURE CALCULATION. 10:56 PUMP 510 BBLS OF PAD AT 5 TO 15 BPM AND 5191 PSI. 11:42 PUMP 15,439# 16/20 PROPPANT AT 2PPA, 15 BPM AND 5260 PSI. 11:55 PUMP 12/18 PROPPANT AT 2PPA TO 10 PPA, 15 BPM AND 4688 PSI. 12:39 PUMP 12/18,10 PPA FLAT STAGE, 15 BPM AND 4768 PSI. 13:06 PUMP RAMP UP FROM 10 PPATO 14.4 PPA , TURBINE TRIPPED OUT, WENTTO FLUSH A LI~-FLE EARLY. FLUSHED TO 20 BBLS SHORT OF PERFS, LEAVING 6718# 12/18 IN PIPE. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $950.00 APC $7,400.00 $7,400.00 ARCO $350.00 $350.00 DOWELL $158,354.00 $158,354.00 HALLIBURTON $0.00 $8,219.00 LI'I-I'LE RED $1,700.00 $6,900.00 PETREDAT $0.00 $0.00 TOTAL FIELD ESTIMATE $167,804.00 $1 82,173.00 ARCO Alaska, Inc. Post Office Box 10036b Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 19, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2F-18 (Permit No. 96-178) Well Completion Report ORI61NAL Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2F-18. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad -- STATE OF ALASKA ALAS;,,-, OIL AND GAS CONSERVATION C,.,,¢IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ClasSification of se'i, vice Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-178 397-002, 397-005 '~. Address ..... 8. 'Apl Number "' P. O. Box 100360, Anchorage, AK 99510 50-029-22720 -;4 d~eati(::J~-of W~ii at ~Llrfa(:;~ ................................... ~?.;..'F...'~'~i:~_-'~ - 9: -unit- or i_e-a~e-Na.m-~ · ~ ....-,'.,¢ ~ ~ ~I '-..,~ 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM---~ ----...:,~.~---,:.i-.? ~ '~'*~,;;¢ ~, Kuparuk River Unit At top of productive interval i ' : ~; ~. ~ ~:' ~ : ::I~'~ ~I 1127' FNL, e93' FEL, Sec. 4, T10N, R9E, UM! "'" ' ¢ ~i~q~i;~, -..: 10. Well Number Attotal depth i ~-- 11 'Field and PoeT' ' ~ 1296 FNL, 659 FEL, Sec. 4, T10N, RDE, UM ~;72~ t Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) t6. :-Le"a~e-lD~signation and Serial No. RKB 41', Pad 97'I ADL 25666, ALK 2587 12. Date Spudded .... i13. E~tte T.D:--~'bached 114. Da(~ Comp., Susp., or Aband':[15. Water depth; if offshore 116. No. of-Completions 12/22/96 ~ 1/16/97I 2/12/97I N/A MSLI One ~'7. Total Depth (MD+TVD)~ 18. PlUg Back DePth (MD+TVD)~i 9. DirectiOnal SurveyS20. DePth ~her5 SSSV set~l. Thickness of Permaf~osi 9715 6385 F~. 9588 6270 F~ ~Yes ~No I N/A Ma/ 1650' (Approx.) 22. Type Electric or Other Logs Run G~Res, G~CCUSLTJ 23. CASING, LINER AND CEMENTING RECORD "CASqUe .... ~-"-~-~;-~¢-~?--;~;l H~LE ................ SIZE ~. PER FT. G~DE TOP BOSOM ~ SIZE CEMENTING RE~RD AMOU~ PULLED 16" 62.5¢ H-40 Sud. 121' 24" 280 sx AS I 9.625" 40¢ L-80 "Sud. ~'¢~ 4' 12~'25" 330 sx ASLW, 1220 sx Class G, 60 sx ........................................................................................... A~ i ........................................................................................... - 7" - ...... 2-6~ -- ~ L-80 "SuH~ ~ 9140' ..... : 8.5" 130SxClassG ' - _9~5_'_ ~ 5" 18¢ L-80 8 ~:75" 137 sx Class G ............................................... F ............................ ........ ~4. Pedorations open to Produ~ion (MD+TVD of Top and Bottom 25. TUB~'~'RECoRD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) ........................................ , ................................................ 3.5" 8979' MD TVD MD TVD ................................................................................................................. 9359'-9383' 6065'-6086' 4 spf 26. AC~D, F~CTURE, CEMENT SQUEEZE, ETC. ................ DEP~ I~ERvAL (MD) AMOU~ & KIND OF MATERIAL USED ............................................... 9359'-9383' pumped 66277¢ of proppant (15071¢ of ............................................................................................................ ¢20/40 and 51206 ¢ of ¢12/18), put 49435¢ in the formation w/6~ ppa of ~12/18 ~ pads. ........... E~ft i 6~2~ ~f prop i~-{~e--~eiib-~e-~ ...................................... ~ _ .. 27. PRODUCTION TEST Date FirSt Production ' iMethod of Operation (FlOwing, g&s lift, etc.) ........ 2/22/97 ~ Gas Lift ~ate of Test!H~'urs Tested PRODUCTION F~ OIL-B~L .... ~AS-~CF " WATER-DeL CH~--~-- ..... i~-~[-~-~- ................ 3/6/97 ~ 24 TEST PERIOD ' 1558 853 63 176 ~ 548 .................... ~ ................................................................................................................................................... Flow Tubing~Casing Pressure ~ALCULA~D · OIL-DEL GAS-MCF WATER-DEL OIL GRAVIS-APl (CORR) Press. 14~ 0 24-HOUR RATE 1676 772 63 24° ...... 28. CORE DATA ,.. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ......... ~,!~_~ ................................................... Form 10-407 Rev. 07-01-80 Submit In Duplicate Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Total pump volumes for this event: Top Kuparuk C 9252' 5969' Category 1. 26256 Bottom Kuparuk C 9260' 5977' Category 2. 100 Top Kuparuk A 9310' 6021' Category 3. 0 Bottom Kuparuk A 9449' 6145' Total: 26356 Total To Date: 26356 Annulus left open - freeze protected with diesel. ............. 31. List of Attachments Summary of Daily Drilling Reports, Surveys i32. I hereby certify that the foregoing is true and correct to the best of my knowledge S ig n eu~ ~__ .... Title. ................................................ . ........ Prepal'ed By IV)~me/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg 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 27: 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: 3/21/97 ARCO ALASKA INC. WELL SUMMARY REPORT WELL:2F-18 RIG-PARKER 245 WELL ID: AX9374 TYPE: -- AFC: AX9374 AFC EST/UL:$ 2900M/ OM STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:12/22/96 START COMP: WI: 0% SECURITY:0 API NUMBER: 50-029-22720-00 FINAL:01/18/97 12/20/96 (D1) TD: 121' (121) SUPV:GRW DAILY:$ 12/21/96 (D2) TD: 121' ( S UP V: GRW 0) DAILY:$ 12/22/96 (D3) TD: 1845' (1724) SUPV:GRW DAILY:$ 12/23/96 (D4) TD: 5143' (3298) SUPV: GRW DAILY:$ 12/24/96 (D5} TD: 5632' (489) SUPV:DCL DAILY:$ 12/25/96 (D6) TD: 5632' ( 0) SUPV:DCL DAILY:$ 12/26/96 (D7) TD: 6349' (717) SUPV: DCL DAILY:$ 12/27/96 (D8) TD. 8660' (2311) SUPV:DCL DAILY:$ MW- 0.0 VISC: 0 PV/YP. 0/ 0 APIWL. 0.0 MOVE RIG Move rig 12.6 miles to DS 2F. 85,966 CUM'$ 85,966 ETD'$ 188,000 EFC'$ 2,797,966 MW: 8.5 VISC: 45 PV/YP: 12/10 APIWL: 20.0 M/U BHA Move drilling rig and utility modules onto DS 2F. Accept rig at 17:00 hrs. 12/21/96. N/U diverter system. 88,395 CUM:$ 174,361 ETD:$ 188,000 EFC:$ 2,886,361 MW: 9.3 VISC: 67 PV/YP: 22/24 APIWL: 7.0 DRILLING @ 2900' Function test diverter. Drill 121' to 1845' 91,565 CUM:$ 265,926 ETD:$ 341,157 EFC:$ 2,824,769 MW: 9.6 VISC: 66 PV/YP: 22/26 APIWL: 7.4 SHORT TRIP Drill from 1845' to 3420' Hole packing off. Circ/cond. mud. Pump iow/hi vis sweep. Drill 3421' to 5143' 84,661 CUM:$ 350,587 ETD:$ 634,145 EFC:$ 2,616,442 MW: 9.6 vise: 66 PV/YP: 26/34 APIWL: 5.5 CEMENT 9-5/8" CSG Drill from 5143' to 5632' Circ and pump lo/hi vis sweep. Pump pill. Wiper trip to HWDP. No problems. Held prejob safety meeting. RIH w/9-5/8" casing to 4086'. 75,163 CUM:$ 425,750 ETD'$ 677,587 EFC $ 2,648,163 MW: 9.6 VISC: 58 PV/YP: 22/26 APIWL: 5.6 DRILL ES CEMENT Finish RIH w/9-5/8" casing. Land casing at 3615' Pump cement. Test all BOPE to 300/5000 psi. 273,310 CUM:$ 699,060 ETD:$ 677,587 EFC:$ 2,921,473 MW: 8.5 VISC: 45 PV/YP: 9/18 APIWL: 12.5 DRILLING Wash out green cement to 1485'. Test casing to 2000'. Drill out ES cementer. Tag green cement at 5230' Test casing to 2000 psi for 30 minutes. Drill cement, LC, FC, FS and 20 new hole to 5642' Perform LOT. Drilling from 5642' to 6349' 91,341 CUM:$ 790,401 ETD:$ 773,644 EFC:$ 2,916,757 MW: 9.0 VISC: 51 PV/YP: 15/27 APIWL: 6.8 PREP TO SHORT TRIP @ 9251' Drilling from 6349' to 7754' Pump lo/hi vis sweep. Pump pill. Drilling from 7754' to 8660' 90,235 CUM:$ 880,636 ETD:$ 1,122,490 EFC:$ 2,658,146 Date: 3/21/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/28/96 (D9) TD: 9343' (683) SUPV: DCL DAILY:$ 12/29/96 (D10) TD: 9591' (248) SUPV:DCL DAILY:$ 12/30/96 (Dll} TD: 9591' ( 0) SUPV:DCL DAILY:$ 12/31/96 (D12) TD: 9710' (119) SUPV:DCL DAILY:$ 01/01/97 (D13) TD: 9710' ( 0) SUPV:DCL DAILY:$ 01/02/97 (D14) TD: 9710' ( 0) SUPV:DCL DAILY:$ 01/03/97 (D15) TD: 9710' ( 0) SUPV:DCL/RLM DAILY:$ 01/04/97 (D16) TD: 9710' ( 0) SUPV: DCL/RLM DAILY:$ 01/05/97 (D17) TD: 6327' ( 0) SUPV: DCL/RLM DAILY:$ MW: 9.0 rISC: 47 PV/YP: 17/21 APIWL: 5.0 MIX LCM Drilling from 8660' to 9251' Perform FIT - 9.1 ppg mud. Raise mud weight to 10.6 ppg. Hi vis mud returns. Formation taking fluids. Hole is breathing. Increase pump rate. Drilling from 9251' to 9343' 113,512 CUM:$ 994,148 ETD:~ 1,225,589 EFC:$ 2,668,559 MW: 11.5 VISC: 46 PV/YP: 46/19 APIWL: 4.6 LD BHA Drilling from 9343' to 9448' . Had 5' drilling break from 9443' to 9448' CBU. No gas. Drilling from 9448' to 9505' Gas cut mud to surface. Increase mud weight to 11.1. Drilling from 9505' to 9591' Continuous oil and gas cut mud. Increase mud weight to 11.5. 149,852 CUM:$ 1,144,000 ETD:$ 1,263,025 EFC:$ 2,780,975 MW: 11.5 VISC: 60 PV/YP: 34/21 APIWL: 4.6 MIX LCM AND CIRC LCM Spot 12 ppg mud. RIH to shoe slow. Circ 100 bbls w/50% returns. Large amount of gas and oil in returns. 103,048 CUM:$ 1,247,048 ETD:$ 1,263,025 EFC:$ 2,884,023 MW: 11.7 VISC: 64 PV/YP: 24/22 APIWL: 4.8 LUBRICATE 11.9 MUD INTO WELL Ream from 9490' to 9591' Drilling from 9591' to 9710' Had gas and oil to surface. Increase mud weight to 11.6. Well dead. 133,999 CUM:$ 1,381,047 ETD:$ 1,280,988 EFC:$ 3,000,059 MW: 12.5 VISC: 68 PV/YP: 43/22 APIWL: 4.6 WAIT ON MUD FROM PLANT Shut well in. Weight up mud to 12.5 ppg. 96,253 CUM:$ 1,477,300 ETD:$ 1,280,988 EFC:$ 3,096,312 MW: 12.5 VISC: 78 PV/YP: 38/32 APIWL: 3.6 STRIP IN HOLE Build mud volume in pits. Work pipe. Monitor pressure. Well is static. Gas and oil to surface. Shut in well. 86,758 CUM:$ 1,564,058 ETD:$ 1,280,988 EFC:$ 3,183,070 MW: 12.1 VISC: 66 PV/YP: 38/18 APIWL: 4.4 STRIP OUT OF HOLE Oil and gas cut mud to 11.0 ppg. Shut well in. Strip in hole. Monitor well while building volume. 334,422 CUM:$ 1,898,480 ETD:$ 1,280,988 EFC:$ 3,517,492 MW: 12.0 VISC: 48 PV/YP: 16/22 APIWL: 4.8 WAIT ON CEMENT Lay 17 ppg cement plug with open end drill pipe. Pump cement. Cement drill pipe in hole. 241,642 CUM:$ 2,140,122 ETD:$ 1,280,988 EFC:$ 3,759,134 MW: 11.5 VISC: 48 PV/YP: 24/16 APIWL: 5.6 WOC Wait on cement. Open well and monitor. Circulate with 12.0 ppg mud and 50% returns. No oil or gas cut. Shut down pump and monitor well. 75,966 CUM:$ 2,216,088 ETD:$ 770,324 EFC:$ 4,345,764 Date: 3/21/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 01/06/97 (D18) TD: 6327' ( 0) SUPV:DCL/RLM DAILY: $ 01/07/97 (D19) TD: 6327' ( 0) SUPV:RLM/GW DAILY:$ 01/08/97 (D20) TD: 5578' ( 0) SUPV:RLM/GW DAILY:$ 01/09/97 (D21) TD: 7076' (1498) SUPV:GRW DAILY:$ 01/10/97 (D22) TD: 7703' (627) SUPV:GRW DAILY:$ 01/11/97 (D23) TD: 8748' (1045) SUPV: GRW DAILY:$ 01/12/97 (D24) TD: 9140' (392) SUPV:GRW DAILY:$ 01/13/97 (D25) TD: 9140' ( 0) SUPV:GRW DAILY: $ 01/14/97 (D26) TD: 9140' ( 0) SUPV: GRW MW: 11.5 rISC: 50 PV/YP: 24/18 APIWL: 5.6 WOC Lay balanced plug with tail at 6325'. Pump cement. CIP @ 0525 hrs. 1/6/97. Circulate on top of plug to clean drill pipe. Lost fluid to formation. WOC. Trip in hole to tag plug. Plug pumped away to formation. Prepare to lay second plug. 368,279 CUM:$ 2,584,367 ETD:$ 770,324 EFC:$ 4,714,043 MW: 11.6 rISC: 49 PV/YP: 22/16 APIWL: 8.2 CIRCULATING CEMENT OUT Laid cement plug @ 6325' CIP @ 0045. Monitor well and on wait on cement. Well static. Tag TOC @ 5941'. Test all BOPE to 300/3000 psi. Well flowing. 75,196 CUM:$ 2,659,563 ETD:$ 770,324 EFC:$ 4,789,239 MW: 11.5 VISC: 43 PV/YP: 18/12 APIWL: 11.8 SIDETRACKING OFF OF CMT PLUG Lay cement plug from 5941' to 5415' CIP @ 0443 hrs. Drill out soft cement to 5578' WOC. 76,751 CUM:$ 2,736,314 ETD:$ 672,790 EFC:$ 4,963,524 MW: 11.1 VISC: 62 PV/YP: 24/26 APIWL: 7.2 DRILLING @ 7800' Drill cement from 5578' to 5700'. Kick off plug @ 5700' Drill to 5773' Lost partial returns. Drill from 5773' to 7076' Circ hi-vis sweep. Monitor well and pump slug. 219,512 CUM:$ 2,955,826 ETD:$ 883,385 EFC:$ 4,972,441 MW: 11.0 VISC: 58 PV/YP: 18/18 APIWL: 7.0 DRILLING @ 7800' Drill from 7076' to 7703' CBU had lots of clay in returns. 77,446 CUM:$ 3,033,272 ETD:$ 978,031 EFC:$ 4,955,241 MW: 10.0 rISC: 43 PV/YP: 15/12 APIWL: 9.6 MAKING WIPER TRIP Drill from 7703' to 7871'. Flow-show dropped from 39% to 26%. Cut MW to 10.6 ppg. Wash/ream to bottom. Spot LCM pill at 7871' Cut MW to 10.0 ppg. Wash/ream to 7871'. Drill from 7871' to 8748'. 84,913 CUM:$ 3,118,185 ETD:$ 1,135,774 EFC:$ 4,882,411 MW: 10.0 VISC: 43 PV/YP: 14/14 APIWL: 6.4 CIRCULATING PRIOR TO CEMENTING Drill from 8748' to 9140' Hold safety meeting. Run 7" casing. 73,809 CUM:$ 3,191,994 ETD:$ 1,194,946 EFC:$ 4,897,048 MW: 0.0 riSC: 43 PV/YP: 20/15 APIWL: 6.6 TESTING BOPE Run 7" casing to 9140' Pump cement. CIP @ 09:19 hrs. 1/13/97. Set packoff. Test to 3000 psi, OK. Freeze protect 9-5/8" x 7" annulus. 195,286 CUM:$ 3,387,280 ETD:$ 1,194,946 EFC:$ 5,092,334 MW: 12.2 rISC: 60 PV/YP: 34/20 APIWL: 4.2 PREPARING FOR LOT Test Hydril 300/3000 psi and remainder of BOPE to 300/5000 psi for 3 min. each. Date: 3/21/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 DAILY:$ 83,027 CUM:$ 3,470,307 ETD:$ 1,194,946 EFC:$ 5,175,361 01/15/97 (D27) TD: 9458' (318) SUPV:GRW DAILY:$ MW: 13.1 rISC: 52 PV/YP: 33/20 APIWL: 3.8 CBU @ TD Tag cement @ 9031.5' Drill cement to 9055', drill float collar, cement to 9139', shoe and new formation to 9150'. Run LOT to 14.4 ppg EWM. Drill from 9150' to 9438' Well flowing slightly. Increase mud weight to 13.1 ppg, no flow. Drill from 9435' to 9455' 89,071 CUM:$ 3,559,378 ETD:$ 1,242,948 EFC:$ 5,216,430 01/16/97 (D28) TD: 9715' (257) SUPV:GRW DAILY:$ MW: 13.1 VISC: 51 PV/YP: 30/21 APIWL: 4.4 RUNNING 5" LINER Drill from 9458' to 9715' Run GR/LDT/CNL. Hold safety meeting. Run 5" liner. 94,104 CUM:$ 3,653,482 ETD:$ 1,281,742 EFC:$ 5,271,740 01/17/97 (D29) TD: 9715' ( 0) SUPV: GRW DAILY:$ MW: 13.1 VlSC: 49 PV/YP: 35/15 APIWL: 5.6 RUNNING 3.5" TUBING RIH w/5" liner. Pump cement. Bump plug w/3200 psi CIP @ 15:30 hours. Test casing/liner to 3400 psi, OK. Run 3.5" tubing. 78,211 CUM:$ 3,731,693 ETD:$ 1,281,742 EFC:$ 5,349,951 01/18/97 (D30} TD: 9715' ( 0) SUPV: GRW DAILY:$ MW: 8.6 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED TO 2F-19 Run 3.5" tubing. Test 7" casing and 3.5" tubing to 3500 psi, no bleed off. Test tubing to 3500 psi, OK. Freeze protect tubing. N/D BOPE. N/U tree. 99,932 CUM:$ 3,831,625 ETD:$ 1,281,742 EFC:$ 5,449,883 01/19/97 (D31} TD: 9715' ( 0) SUPV:GRW DAILY:$ MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED TO 2F-19 Rig released 02:30 hrs. 1/19/97. 172,994 CUM:$ 4,004,619 ETD:$ 1,281,742 EFC:$ 5,622,877 End of WellSummary for Well:AX9374 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(2F-18(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-18 FRAC, FRAC SUPPORT 0123971311.1 DATE DAILY WORK UN1T NUMBER 02/08/97 PERFORATE 2 1/2" HSD 8337 DAY OPERATION COMPLEI'E SUCCESSFUL [ KEY PERSON SUPERVISOR 3 NO NO ] SWS WALSH JORDAN Initial Tbg Press I Final Tbg Press Initial Inner Ann I Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 750 PSI 0 PSI 0 PSI 0 PSI 0 PSI DAILY SUMMARY ! PERFORATED 9379-83'. S'IRANDED CABLE ARMOR. RD FOR NIGHT TO REPAIR CABLE. TIME LOG ENTRY 08:00 MIRU-SWS WALSH & CREW 10:00 ATI'I~VIPTED TO PRESSURE TEST. PUMP TRUCK HAD WATER IN TANK. FROZE FLOW TUBES.CALLED FOR HEATERS. 12:00 RIH. WT/GR/CCL/10' GUN. SET DOWN @2442' 60+ DEGREES. WAfflNG FOR PUMP TRUCK TO FINISH THAWING LINES. 14:00 PUMPING 2 BPM. SET DOWN AT 4200' 70+ DEGREES. PUMP TRUCK NEEDS SECOND LOAD. HAD TO CHANGE OUT CHOKES. , 17:00 PUMPING 2.5 BPM. MOVED DOWN EASILY. PUMPED 239 BARRELS DIESEL TOTAL IN TUBING AND INNER ANULUS. 18:15 TIED IN AND SHOT GUN. 9379-83' 4 SPF ORIENTED 17 DEG CW FROM HIGH SIDE. SHOT WYI'I 1 1600 PSI SURFACE PRESSURE. PRESSURE DROPPED SLIGHTLY AFFER SHOT AND DESCENDED GRADUALLY WHILE TOOH. , 19:00 STRANDED ARMOR IN FLOW TUBES AT 850'. 21:00 FINISI-IED FIELD REPAIR. SAFELY OOH. BEGAN RD. 22:00 RDMO. REI'tJRN TO PB TO FINISH REPAIRING CABLE. · f-SUN DRILLING SERVICES ANCHOP_AGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18 500292272000 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 011697 MWD SURVEY JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 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 VERT. SECT. .00 .00 -138.00 121.00 121.00 -17.00 193.12 193.12 55.12 284.96 284.95 146.95 356.00 355.97 217.97 0 0 N .00 E .00 .00N .00E 0 0 N .00 E .00 .00N .00E 0 25 N 64.59 E .58 .liN .24E 1 1 S 32.84 E 1.16 .44S .99E 1 45 S 21.00 E 1.09 1.98S 1.73E .00 .00 -.08 .58 2.22 463.54 463.34 325.34 554.75 554.14 416.14 644.71 643.35 505.35 728.29 725.73 587.73 826.76 821.44 683.44 4 11 S 20.77 E 2.27 7.19S 3.71E 6 23 S 10.77 E 2.61 15.29S 5.84E 8 19 S 9.05 E 2.17 26.65S 7.80E 11 3 S 11.31 E 3.30 40.49S 10.32E 15 59 S 4.65 E 5.24 63.28S 13.28E 7.66 15.99 27.51 41.57 64.55 916.73 907.16 769.16 1008.11 992.70 854.70 1100.11 1076.84 938.84 1193.65 1159.21 1021.21 1286.32 1237.40 1099.40 19 20 S 2.03 E 3.83 90.53S 14.81E 21 47 S 1.76 E 2.68 122.61S 15.87E 25 52 S 1.98 E 4.44 159.75S 17.08E 30 37 S 1.25 E 5.10 203.99S 18.31E 34 16 S 1.95 E 3.96 253.69S 19.71E 91.73 123.60 160.52 204.46 253.82 1379.30 1313.62 1175.62 1472.28 1388.65 1250.65 1566.18 1462.16 1324.16 1659.23 1531.29 1393.29 1753.26 1597.45 1459.45 35 35 S 3.62 E 1.74 306.87S 22.31E 36 47 S 5.22 E 1.64 361.59S 26.55E 40 10 S 8.19 E 4.10 419.59S 33.43E 43 49 S 8.06 E 3.93 481.22S 42.23E 46 43 S 8.32 E 3.09 547.35S 51.75E 306.79 361.54 419.92 482.17 548.98 1845.62 1659.75 1521.75 1941.68 1722.52 1584.52 2036.20 1781.92 1643.92 2130.30 1837.88 1699.88 2220.09 1888.19 1750.19 48 25 S 8.91 E 1.90 614.75S 61.96E 49 57 S 10.99 E 2.28 686.34S 74.54E 52 9 S 11.75 E 2.42 758.39S 89.03E 54 50 S 11.16 E 2.90 832.53S 104.05E 56 59 S 11.90 E 2.48 905.38S 118.92E 617.15 689.81 763.22 838.76 913.01 2312.53 1936.72 1798.72 2405.65 1981.97 1843.97 2500.18 2023.81 1885.81 2778.40 2138.03 2000.03 3061.47 2244.96 2106.96 59 40 S 11.91 E 2.90 982.36S 135.15E 62 10 S 10.84 E 2.88 1062.14S 151.19E 65 16 S 10.83 E 3.27 1145.38S 167.12E 66 15 S 9.60 E .54 1395.03S 212.09E 69 21 S 8.01 E 1.22 1654.00S 252.17E 991.54 1072.82 1157.50 1411.05 1673.10 3338.25 2339.36 2201.36 3622.66 2437.74 2299.74 3995.35 2565.58 2427.58 4369.09 2689.19 2551.19 4746.54 2821.09 2683.09 70 45 S' 7.35 E .55 68 46 S 8.31 E .76 71 5 S 9.22 E .67 70 16 S 9.30 E .22 68 49 S 10.31 E .46 1911.82S 286.93E 1933.23 2176.13S 323.26E 2200.01 2522.03S 376.61E 2549.99 2870.13S 433.37E 2902.66 3218.57S 493.57E 3256.18 RECEIVED Gas Oo~s. Commisskm SPE f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18 500292272000 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 011697 MWD SURVEY JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 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 VERT. SECT. 5120.62 2952.98 2814.98 69 53 S 9.54 E .34 3563.37S 553.89E 5547.50 3101.01 2963.01 69 31 S 8.56 E .23 3958.76S 616.88E 5700.00 3155.38 3017.38 68 41 S 10.12 E 1.10 4099.33S 639.99E 5778.39 3185.48 3047.48 66 8 S 10.26 E 3.26 4170.55S 652.79E 5874.52 3227.12 3089.12 62 31 S 10.93 E 3.82 4255.70S 668.71E 3606.11 4006.46 4148.91 4221.24 4307.81 5967.39 3272.34 3134.34 59 11 S 10.95 E 3.59 4335.33S 684.10E 6058.58 3320.68 3182.68 56 46 S 10.45 E 2.69 4411.28S 698.46E 6155.61 3375.56 3237.56 54 19 S 10.99 E 2.56 4489.88S 713.33E 6250.95 3432.77 3294.77 51 54 S 11.58 E 2.60 4564.65S 728.25E 6343.56 3491.12 3353.12 49 58 S 11.32 E 2.08 4635.12S 742.52E 4388.83 4466.07 4546.01 4622.16 4693.96 6436.30 3551.95 3413.95 48 1 S 11.56 E 2.11 4703.71S 756.40E 6529.85 3616.02 3478.02 45 30 S 13.34 E 3.04 4770.26S 771.07E 6622.29 3682.63 3544.63 42 16 S 12.76 E 3.51 4832.68S 785.55E 6715.68 3753.35 3615.35 39 16 S 12.11 E 3.25 4892.23S 798.69E 6810.48 3828.09 3690.09 36 38 S 11.30 E 2.82 4949.32S 810.53E 4763.86 4831.85 4895.72 4956.56 5014.77 6904.16 3904.76 3766.76 33 28 S 12.23 E 3.42 5002.00S 821.48E 6996.82 3983.33 3845.33 30 32 S 11.82 E 3.18 5050.03S 831.72E 7278.37 4227.82 4089.82 28 53 S 10.45 E .63 5186.95S 858.71E 7558.98 4473.60 4335.60 28 47 S 10.69 E .05 5320.05S 883.55E 7839.98 4720.02 4582.02 28 38 S 10.55 E .06 5452.79S 908.44E 5068.49 5117.51 5256.92 5392.23 5527.19 8117.34 4963.94 4825.94 28 12 S 11.76 E .26 5582.31S 933.97E 8396.59 5209.90 5071.90 28 19 S 11.47 E .07 5711.82S 960.59E 8673.31 5454.01 5316.01 27 52 S 11.03 E .18 5839.63S 986.02E 8946.35 5696.40 5558.40 26 56 S 11.73 E .36 5962.83S 1010.80E 9064.19 5801.57 5663.57 26 41 S 12.36 E .32 6014.82S 1021.89E 5659.06 5791.09 5921.25 6046.76 6099.82 9384.96 6087.93 5949.93 26 52 S 12.63 E .07 6155.95S 1053.17E 9641.69 6318.36 6180.36 25 25 S 10.58 E .67 6266.75S 1075.98E 9715.00 6384.57 6246.57 25 25 S 10.58 E .03 6297.68S 1081.75E 6244.02 6356.98 6388.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6389.91 FEET AT SOUTH 9 DEG. 44 MIN. EAST AT MD = 9715 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 171.49 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD WINDOW POINT SURVEY AT 5700' MD PROJECTED SURVEY TO TD AT 9715' MD SPt f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18 500292272000 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 011697 JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 OPERATOR: ARCO ALASKA, INC. FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -138.00 .00 N .00 E 1000.00 985.17 847.17 119.60 S 15.77 E 2000.00 1759.71 1621.71 730.41 S 83.21 E 3000.00 2222.95 2084.95 1597.19 S 244.00 E 4000.00 2567.09 2429.09 2526.37 S 377.32 E .00 14.83 14.83 240.29 225.45 777.05 536.77 1432.91 655.86 5000.00 2911.51 2773.51 3451.67 S 535.12 E 6000.00 3289.04 3151.04 4362.83 S 689.42 E 7000.00 3986.07 3848.07 5051.61 S 832.05 E 8000.00 4860.53 4722.53 5528.03 S 922.67 E 9000.00 5744.23 5606.23 5986.63 S 1015.74 E 2088.49 655.58 2710.96 622.46 3013.93 302.98 3139.47 125.54 3255.77 116.29 9715.00 6384.57 6246.57 6297.68 S 1081.75 E 3330.43 74.66 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE. DRILLING SERVICES ANCHOR3~GE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER LrNIT/2F-18 500292272000 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 011697 JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA, INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 38.00 38.00 138.00 138.00 238.00 238.00 338.02 338.00 -138.00 -100.00 .00 100.00 200.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .24 N .54 E .00 .00 1.47 S 1.53 E .02 .02 438.13 438.00 538.50 538.00 639.30 638.00 740.81 738.00 844.02 838.00 300.0 400.0 500.0 600.0 70O .0 0 5.46 S 3.05 0 13.52 S 5.50 0 25.87 S 7.67 0 42.92 S 10.78 0 68.14 S 13.64 E .13 .11 E .50 .37 E 1.30 .80 E 2.81 1.51 E 6.02 3.21 949.41 938.00 800.00 1057.29 1038.00 900.00 1169.18 1138.00 1000.00 1287.06 1238.00 1100.00 1409.29 1338.00 1200.00 101.35 S 15.19 141.73 S 16.48 191.80 S 18.02 254.12 S 19.73 324.28 S 23.42 11 19 31 49 71 .41 5.40 .29 7.88 .18 11.89 .06 17.88 .29 22.23 1534.85 1438.00 1300.00 1668.57 1538.00 1400.00 1812.85 1638.00 1500.00 1965.74 1738.00 1600.00 2130.52 1838.00 1700.00 399.82 S 30.76 487.66 S 43.14 590.53 S 58.17 704.42 S 78.05 832.71 S 104.08 96 130 174 227 292 .85 25.56 .57 33.73 .85 44.27 .74 52.89 .52 64.78 2315.10 1938.00 1800.00 2534.10 2038.00 1900.00 2778.33 2138.00 2000.00 3041.84 2238.00 2100.00 3334.12 2338.00 2200.00 984.54 S 135.60 1175.64 S 172.91 1394.96 S 212.08 1635.83 S 249.59 1907.95 S 286.43 377 496 640 803 996 .10 84.58 .10 119.00 .33 144.22 .84 163.52 .12 192.27 3623.37 2438.00 2300.00 3910.21 2538.00 2400.00 4217.44 2638.00 2500.00 4513.66 2738.00 2600.00 4793.34 2838.00 2700.00 2176.79 S 323.36 2442.52 S 363.71 2729.26 S 410.30 3004.42 S 455.36 3261.51 S 501.38 1185 1372 1579 1775 1955 .37 189.26 .21 186.83 .44 207.23 .66 196.22 .34 179.68 5077.06 2938.00 2800.00 5367.33 3038.00 2900.00 5652.17 3138.00 3000.00 5897.75 3238.00 3100.00 6090.18 3338.00 3200.00 3523.03 S 547.11 3791.85 S 591.75 4055.46 S 632.16 4275.86 S 672.60 4437.28 S 703.25 2139.06 2329.33 2514.17 2659.75 2752.18 183.72 190.28 184.83 145.59 92.43 SPE f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18 500292272000 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 011697 JOB NI/MBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA, INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6259.43 3438.00 3300.00 4571.18 S 729.58 E 2821.43 69.24 6415.45 3538.00 3400.00 4688.52 S 753.29 E 2877.45 56.02 6560.90 3638.00 3500.00 4791.61 S 776.10 E 2922.90 45.46 6695.75 3738.00 3600.00 4879.80 S 796.00 E 2957.75 34.84 6822.78 3838.00 3700.00 4956.47 S 811.97 E 2984.78 27.04 6943.71 3938.00 3800.00 5022.96 S 825.99 E 3005.71 20.93 7060.30 4038.00 3900.00 5081.60 S 838.33 E 3022.30 16.59 7175.78 4138.00 4000.00 5138.19 S 849.72 E 3037.78 15.48 7290.00 4238.00 4100.00 5192.48 S 859.73 E 3052.00 14.23 7404.23 4338.00 4200.00 5246.77 S 869.75 E 3066.23 14.23 7518.36 4438.00 4300.00 5300.82 S 879.92 E 3080.36 14.13 7632.47 4538.00 4400.00 5354.84 S 890.12 E 3094.47 14.11 7746.52 4638.00 4500.00 5408.74 S 900.24 E 3108.52 14.05 7860.47 4738.00 4600.00 5462.45 S 910.24 E 3122.47 13.95 7974.42 4838.00 4700.00 5516.15 S 920.25 E 3136.42 13.95 8087.91 4938.00 4800.00 5568.70 S 931.14 E 3149.91 13.49 8201.38 5038.00 4900.00 5621.19 S 942.06 E 3163.38 13.47 8314.91 5138.00 5000.00 5673.85 S 952.89 E 3176.91 13.53 8428.51 5238.00 5100.00 5726.66 S 963.60 E 3190.51 13.60 8542.07 5338.00 5200.00 5779.42 S 974.28 E 3204.07 13.57 8655.19 5438.00 5300.00 5831.32 S 984.40 E 3217.19 13.12 8768.31 5538.00 5400.00 5883.23 S 994.51 E 3230.31 13.12 8880.84 5638.00 5500.00 5933.77 S 1004.77 E 3242.84 12.52 8993.01 5738.00 5600.00 5983.53 S 1015.10 E 3255.01 12.17 9104.96 5838.00 5700.00 6032.71 S 1025.81 E 3266.96 11.95 9216.89 5938.00 5800.00 6081.82 S 1036.57 E 3278.89 11.92 9328.99 6038.00 5900.00 6131.25 S 1047.64 E 3290.99 12.10 9441.10 6138.00 6000.00 6180.72 S 1058.72 E 3303.10 12.11 9552.72 6238.00 6100.00 6229.20 S 1068.96 E 3314.72 11.62 9663.44 6338.00 6200.00 6275.92 S 1077.69 E 3325.44 10.72 9715.00 6384.57 6246.57 6297.68 S 1081.75 E 3330.43 4.99 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPE] _-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18PB1 500292272070 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 122996 MWD SURVEY JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 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 VERT. SECT. .00 .00 -138.00 121.00 121.00 -17.00 193.12 193.12 55.12 284.96 284.95 146.95 356.00 355.97 217.97 0 0 0 0 0 25 1 1 1 45 N .00 E .00 .00N .00E N .00 E .00 .00N .00E N 64.59 E .58 .liN .24E S 32.84 E 1.16 .44S .99E S 21.00 E 1.09 1.98S 1.73E .00 .00 -.08 .58 2.22 463.54 463.34 325.34 554.75 554.14 416.14 644.71 643.35 505.35 728.29 725.73 587.73 826.76 821.44 683.44 4 11 6 23 8 19 11 3 15 59 S 20.77 E 2.27 7.19S 3.71E S 10.77 E 2.61 15.29S 5.84E S 9.05 E 2.17 26.65S 7.80E S 11.31 E 3.30 40.49S 10.32E S 4.65 E 5.24 63.28S 13.28E 7.66 15.99 27.51 41.57 64.55 916.73 907.16 769.16 1008.11 992.70 854.70 1100.11 1076.84 938.84 1193.65 1159.21 1021.21 1286.32 1237.40 1099.40 19 21 25 3O 34 20 47 52 37 16 S 2.03 E 3.83 90.53S 14.81E S 1.76 E 2.68 122.61S 15.87E S 1.98 E 4.44 159.75S 17.08E S 1.25 E 5.10 203.99S 18.31E S 1.95 E 3.96 253.69S 19.71E 91.73 123.60 160.52 204.46 253.82 1379.30 1313.62 1175.62 1472.28 1388.65 1250.65 1566.18 1462.16 1324.16 1659.23 1531.29 1393.29 1753.26 1597.45 1459.45 35 35 36 47 40 10 43 49 46 43 S 3.62 E 1.74 306.87S 22.31E S 5.22 E 1.64 361.59S 26.55E S 8.19 E 4.10 419.59S 33.43E S 8.06 E 3.93 481.22S 42.23E S 8.32 E 3.09 547.35S 51.75E 306.79 361.54 419.92 482.17 548.98 1845.62 1659.75 1521.75 1941.68 1722.52 1584.52 2036.20 1781.92 1643.92 2130.30 1837.88 1699.88 2220.09 1888.19 1750.19 48 25 49 57 52 9 54 50 56 59 S 8.91 E 1.90 614.75S 61.96E S 10.99 E 2.28 686.34S 74.54E S 11.75 E 2.42 758.39S 89.03E S 11.16 E 2.90 832.53S 104.05E S 11.90 E 2.48 905.38S 118.92E 617.15 689.81 763.22 838.76 913.01 2312.53 1936.72 1798.72 2405.65 1981.97 1843.97 2500.18 2023.81 1885.81 2778.40 2138.03 2000.03 3061.47 2244.96 2106.96 59 40 62 10 65 16 66 15 69 21 S 11.91 E 2.90 982.36S 135.15E S 10.84 E 2.88 1062.14S 151.19E S 10.83 E 3.27 1145.38S 167.12E S 9.60 E .54 1395.03S 212.09E S 8.01 E 1.22 1654.00S 252.17E 991.54 1072.82 1157.50 1411.05 1673.10 3338.25 2339.36 2201.36 3622.66 2437.74 2299.74 3995.35 2565.58 2427.58 4369.09 2689.19 2551.19 4746.54 2821.09 2683.09 70 45 68 46 71 5 70 16 68 49 S 7.35 E .55 1911.82S 286.93E S 8.31 E .76 2176.13S 323.26E S 9.22 E .67 2522.03S 376.61E S 9.30 E .22 2870.13S 433.37E S 10.31 E .46 3218.57S 493.57E 1933.23 2200.01 2549.99 2902.66 3256.18 RECEIVED MAR 0 5 1997 Oti & Gas Cons. OomPh Anchorage SP~ f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18PB1 500292272070 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 122996 MWD SURVEY JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 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 VERT. SECT. 5120.62 2952.98 2814.98 5547.50 3101.01 2963.01 5690.57 3151.96 3013.96 5971.39 3257.29 3119.29 6158.65 3332.84 3194.84 69 53 69 31 68 44 67 11 65 11 S 9.54 E .34 3563.37S 553.89E S 8.56 E .23 3958.76S 616.88E S 10.05 E 1.12 4090.68S 638.48E S 12.01 E .85 4346.13S 688.25E S 11.94 E 1.07 4513.71S 723.80E 3606.11 4006.46 4140.12 4400.13 4571.12 6252.54 3373.21 3235.21 6345.19 3414.57 3276.57 6438.47 3458.27 3320.27 6533.60 3505.82 3367.82 6627.55 3555.50 3417.50 63 52 63 5 61 1 58 59 57 9 S 10.26 E 2.15 4596.88S 740.12E S 7.90 E 2.43 4678.72S 753.21E S 8.26 E 2.26 4760.30S 764.79E S 7.66 E 2.20 4841.88S 776.20E S 7.23 E 2.00 4920.93S 786.53E 4655.79 4738.67 4821.06 4903 .43 4983.14 6722.35 3608.21 3470.21 6817.27 3663.55 3525.55 6911.97 3721.12 3583.12 7003.62 3778.95 3640.95 7096.97 3840.07 3702.07 55 53 51 5O 48 16 22 44 0 11 S 6.93 E 1.99 4999.11S 796.24E S 6.69 E 2.01 5075.67S 805.39E S 6.21 E 1.78 5150.37S 813.84E S 6.36 E 1.90 5221.03S 821.62E S 5.79 E 1.99 5291.18S 829.09E 5061.90 5138.97 5214.10 5285.13 5355.61 7189.59 3902.89 3764.89 7283.49 3968.94 3830.94 7377.07 4037.30 3899.30 7471.50 4108.81 3970.81 7564.66 4181.61 4043.61 46 22 44 11 41 56 39 34 37 37 S 5.08 E 2.03 5358.91S 835.54E S 5.12 E 2.33 5425.37S 841.47E S 5.22 E 2.41 5488.99S 847.23E S 5.80 E 2.54 5550.34S 853.14E S 5.42 E 2.10 5608.17S 858.82E 5423.56 5490.15 5553.93 5615.48 5673.52 7655.94 4254.87 4116.87 7751.90 4333.95 4195.95 7846.76 4414.02 4276.02 7939.94 4494.20 4356.20 8032.13 4575.07 4437.07 35 35 33 21 31 28 29 45 27 36 S 5.25 E 2.23 5662.37S 863.88E S 4.72 E 2.36 5716.48S 868.61E S 7.10 E 2.40 5767.04S 873.82E S 6.92 E 1.84 5814.14S 879.61E S 6.68 E 2.34 5858.07S 884.85E 5727.87 5782.08 5832 86 5880.29 5924 51 8122.98 4656.40 4518.40 8216.42 4741.64 4603.64 8310.38 4828.67 4690.67 8403.77 4915.71 4777.71 8496.89 5003.14 4865.14 25 16 23 1 21 12 21 17 18 54 S 5.93 E 2.60 5898.26S 889.30E S 5.32 E 2.41 5936.30S 893.06E S 5.82 E 1.95 5971.51S 896.49E S 6.43 E .25 6005.16S 900.10E S 5.18 E 2.60 6036.99S 903.35E 5964 93 6003.10 6038 43 6072.25 6104 20 8592.39 5094.07 4956.07 8685.46 5183.50 5045.50 8780.33 5274.87 5136.87 8874.31 5365.90 5227.90 8966.95 5456.62 5318.62 16 37 15 31 15 40 13 3 10 18 S 5.14 E 2.40 6066.01S 905.98E S 6.26 E 1.22 6091.65S 908.53E S 6.08 E .17 6117.02S 911.27E S 5.85 E 2.79 6140.21S 913.70E S 8.45 E 3.02 6158.83S 915.98E 6133 29 6159.02 6184.52 6207.82 6226.57 SPE _'-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18PB1 500292272070 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 122996 MWD SURVEY JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 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 9060.58 5549.04 5411.04 7 55 S 12.08 E 2.61 6173.43S 918.57E 9150.83 5638.70 5500.70 5 7 S 15.08 E 3.12 6183.42S 920.92E 9240.67 5728.30 5590.30 3 2 S 8.08 E 2.39 6189.66S 922.30E 9433.88 5921.26 5783.26 2 42 S 7.33 E .17 6199.26S 923.60E 9591.00 6078.21 5940.21 2 42 S 7.33 E .00 6206.63S 924.55E VERT. SECT. 6241.40 6251.62 6257.99 6267.68 6275.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6275.11 FEET AT SOUTH 8 DEG. 28 MIN. EAST AT MD = 9591 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 171.49 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY TO TD AT 9591' MD SPt f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18PB1 500292272070 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 122996 JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 OPERATOR: ARCO ALASKA, INC. FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION .00 .00 -138.00 .00 N .00 E .00 1000.00 985.17 847.17 119.60 S 15.77 E 14.83 2000.00 1759.71 1621.71 730.41 S 83.21 E 240.29 3000.00 2222.95 2084.95 1597.19 S 244.00 E 777.05 4000.00 2567.09 2429.09 2526.37 S 377.32 E 1432.91 14.83 225.45 536.77 655.86 5000.00 2911.51 2773.51 3451.67 S 535.12 E 2088.49 6000.00 3268.37 3130.37 4371.93 S 693.74 E 2731.63 7000.00 3776.62 3638.62 5218.28 S 821.31 E 3223.38 8000.00 4546.59 4408.59 5843.28 S 883.12 E 3453.41 9000.00 5489.13 5351.13 6164.68 S 916.85 E 3510.87 655.58 643.13 491.75 230.03 57.46 9591.00 6078.21 5940.21 6206.63 S 924.55 E 3512.79 1.93 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. KUPARUK RIVER UNIT/2F-18PB1 500292272070 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 122996 JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA, INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -138.00 38.00 38.00 -100.00 138.00 138.00 .00 238.00 238.00 100.00 338.02 338.00 200.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .24 N .54 E .00 .00 1.47 S 1.53 E .02 .02 438.13 438.00 300.00 538.50 538.00 400.00 639.30 638.00 500.00 740.81 738.00 600.00 844.02 838.00 700.00 5.46 S 3.05 E .13 .11 13.52 S 5.50 E .50 .37 25.87 S 7.67 E 1.30 .80 42.92 S 10.78 E 2.81 1.51 68.14 S 13.64 E 6.02 3.21 949.41 938.00 800.00 1057.29 1038.00 900.00 1169.18 1138.00 1000.00 1287.06 1238.00 1100.00 1409.29 1338.00 1200.00 101.35 S 15.19 E 141.73 S 16.48 E 191.80 S 18.02 E 254.12 S 19.73 E 324.28 S 23.42 E 11.41 5.40 19.29 7.88 31.18 11.89 49.06 17.88 71.29 22.23 1534.85 1438.00 1300.00 1668.57 1538.00 1400.00 1812.85 1638.00 1500.00 1965.74 1738.00 1600.00 2130.52 1838.00 1700.00 399.82 S 30.76 E 487.66 S 43.14 E 590.53 S 58.17 E 704.42 S 78.05 E 832.71 S 104.08 E 96.85 25.56 130.57 33.73 174.85 44.27 227.74 52.89 292.52 64.78 2315.10 1938.00 1800.00 2534.10 2038.00 1900.00 2778.33 2138.00 2000.00 3041.84 2238.00 2100.00 3334.12 2338.00 2200.00 984.54 S 135.60 E 1175.64 S 172.91 E 1394.96 S 212.08 E 1635.83 S 249.59 E 1907.95 S 286.43 E 377.10 84.58 496.10 119.00 640.33 144.22 803.84 163.52 996.12 192.27 3623.37 2438.00 2300.00 3910.21 2538.00 2400.00 4217.44 2638.00 2500.00 4513.66 2738.00 2600.00 4793.34 2838.00 2700.00 2176.79 S 323.36 E 2442.52 S 363.71 E 2729.26 S 410.30 E 3004.42 S 455.36 E 3261.51 S 501.38 E 1185.37 189.26 1372.21 186.83 1579.44 207.23 1775.66 196.22 1955.34 179.68 5077.06 2938.00 2800.00 5367.33 3038.00 2900.00 5652.06 3138.00 3000.00 5921.62 3238.00 3100.00 6170.94 3338.00 3200.00 3523.03 S 547.11 E 3791.85 S 591.75 E 4055.34 S 632.22 E 4301.25 S 678.71 E 4524.63 S 726.11 E 2139.06 183.72 2329.33 190.28 2514.06 184.73 2683.62 169.56 2832.94 149.32 SPt Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASICA, INC. KUPARUK RIVER UNIT/2F-18PB1 500292272070 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 122996 JOB NUMBER: AK-MM-60201 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA, INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6396.50 3438.00 3300.00 4723.92 S 759.52 E 2958.50 125.55 6595.28 3538.00 3400.00 4894.03 S 783.12 E 3057.28 98.78 6774.31 3638.00 3500.00 5041.37 S 801.36 E 3136.31 79.03 6939.23 3738.00 3600.00 5171.65 S 816.15 E 3201.23 64.93 7093.87 3838.00 3700.00 5288.88 S 828.86 E 3255.87 54.63 7240.33 3938.00 3800.00 5395.40 S 838.79 E 3302.33 46.47 7378.01 4038.00 3900.00 5489.62 S 847.28 E 3340.01 37.68 7509.34 4138.00 4000.00 5574.30 S 855.57 E 3371.34 31.32 7635.20 4238.00 4100.00 5650.35 S 862.78 E 3397.20 25.86 7756.75 4338.00 4200.00 5719.13 S 868.83 E 3418.75 21.55 7874.87 4438.00 4300.00 5781.61 S 875.63 E 3436.87 18.13 7990.24 4538.00 4400.00 5838.69 S 882.58 E 3452.24 15.37 8102.64 4638.00 4500.00 5889.63 S 888.41 E 3464.64 12.40 8212.46 4738.00 4600.00 5934.76 S 892.92 E 3474.46 9.83 8320.38 4838.00 4700.00 5975.11 S 896.85 E 3482.38 7.92 8427.69 4938.00 4800.00 6013.79 S 901.07 E 3489.69 7.30 8533.73 5038.00 4900.00 6048.88 S 904.43 E 3495.73 6.05 8638.23 5138.00 5000.00 6079.04 S 907.15 E 3500.23 4.49 8742.03 5238.00 5100.00 6106.73 S 910.17 E 3504.03 3.80 8845.61 5338.00 5200.00 6133.55 S 913.01 E 3507.61 3.58 8948.01 5438.00 5300.00 6155.36 S 915.49 E 3510.01 2.39 9049.43 5538.00 5400.00 6171.93 S 918.24 E 3511.43 1.42 9150.13 5638.00 5500.00 6183.34 S 920.90 E 3512.13 .70 9250.39 5738.00 5600.00 6190.17 S 922.37 E 3512.39 .26 9350.53 5838.00 5700.00 6195.35 S 923.10 E 3512.53 .14 9450.64 5938.00 5800.00 6200.05 S 923.70 E 3512.64 .11 9550.75 6038.00 5900.00 6204.74 S 924.31 E 3512.75 .11 9591.00 6078.21 5940.21 6206.63 S 924.55 E 3512.79 .04 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS i ', SURVEY CALCULATION AND FIELD WORKSHEET Job.o. 0450-81689 Sidetrack No, 1 Page I of 2 Company ARCO ALASKA, INC, Rig Contractor & No, PARKER DRILLING CO, - #245, Field KUPARUK RI~ER UNIT ,,,~i WELL DATA ,,. Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -275.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE] SS~ Target Description Target Coord. E/W Slot Coord. E/W -1713.00 Magn. Declination 27.860 Calculation Method MINIMUM CURVATURE Target Direction (DB) Build\Walk\DL per: 100ff[~ 30m[--] lomE] Vert. Sec. Azim. 171.49 Magn. to Map Corr. 27.860 Map North to: OTHER i i ! SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (OD) (FT) (FT) (Fl') (FT) (Per mo FT) Drop (-) Left (-) MWD 5700,00 68,69 169,88 3155,55 4150,07 -4099,56 640,06 TIE IN POINT -- - 09-JAN-97 MWD 5778.39 66.14 . 169.74 78.39 3185.65 4221.48 -4170.79 652.86 3.26 -3.25 -0.18 6 3/4'MACH 1XL-AKO-1.2 DEG 09-JAN-97 MWD 5874.52 62.52 169.07 96.13 3227.29 4308.05 -4255.94 668.78 3.82 -3.77 -0.70 -- 09-JAN-97 MWD 5967,39 59,19 169,05 92,87 3272,51 4389,08 -4335,57 684,17 3,59 -3,59 -0,02 09-JAN-97 MWD 6058,58 56,77 169,55 91,1 9 3320,86 4466,33 -4411,53 698,53 2,69 -2,65 0,55 09-JAN-97 MWD 6155,61 54,33 169,01 97,03 3375,74 4546,28 -4490,15 713.41 2.56 -2,51 -0,56 09-JAN-97 MWD 6250,95 51,90 168,42 95,34 3432,96 4622,44 -4564,92 728,32 2,60 -2,55 -0,62 09-JAN-97 MWD 6343,56 49,98 1 68,68 92,61 3491,32 4694,25 -4635,40 742,60 2,08 -2,07 0,28 09-JAN-97 MWD 6436,30 48,03 168,44 92,74 3552,15 4764,16 -4704,00 756.48 2,11 -2,10 -0,26 09-JAN-97 MWD 6529,85 45,50 166.68 93,55 3616,23 4832,14 -4770.55 771,14 3,03 -2,70 -1,88 09-JAN-97 MWD 6622,29 42,28 167,24 92,44 3682,84 4896,02 -4632,97 785,61 3,51 -3,48 0,61 · . 09-JAN-97 MWD 6715,68 39,27 167,89 93,39 3753,56 4958,86 -4892,53 798,75 3,25 -3,22 0,70 09-JAN-97 MWD 6810.48 38.64 1 68.70 94.80 3828.30 5015.07 -4949.61 810.59 2.82 -2.77 0.85 09-JAN-97 MWD 6904,16 33,48 167,77 93,68 3904.97 5068,79 -5002,29 821,54 3,42 -3,37 -0,99 ~. 09-JAN-97 MWD 6996,82 30,54 168,18 92,66 3983,53 5117,81 -5050,32 831,78 3,18 -3,17 0,44 10-JAN-97 MWD 7278.37 28.90 169.55 281.55 4228.04 5257.23 -5187.25 858.78 0.63 -0.58 0.49 10-JAN-97 MWD 7558.98 28.80 169.31 280.61 4473.83 5392.54 -5320.36 863.61 0.05 -0.04 -0.09 ~ ~; F,-) ................ ' ' i~-~ ~';, , '- 11-JAN-97 MWD 7839.98 28.65 169.45 281.00 4720.24 5527.50 -5453.09 908.50 0.06 -0.05 0.05 ~-~ 11-JAN-97 MWD 8117.34 28.20 168.24 277.36 4964.17 5859.38 -5582.62 934.03 0.26 -0.16 -0.44 .. _ '.(~ --.J. '~ . ~ .~ 11 -JAN-97 MWD 8396.59 28.32 1 58.53 279.25 5210.13 5791.40 -5712.13 960.65 0.07 0.04 0.10 ,. 11 -JAN-97 MWD 8673.31 27.87 168.97 276.72 5454.25 5921.56 -5839.94 986.08 0.18 -0.16 0.16 12-JAN-97 MWD 8946.35 26.94 1 58.27 273.04 5696.64 6047.08 -5963.14 1010.86 0.36 -0.34 -0.26 12-JAN-97 MWD 9064.19 26.69 167.64 117.64 5801.81 6100.14 -6015.13 1021.96 0.32 -0.21 -0.53 ,_ 15-JAN-97 MWD 9364.96 26.88 167.37 320.77 6088.16 6244.34 -6156.26 1053.23 0.07 0.06 -0.08 4 3/4'MACH 1XL-AKO-1.2deg. I ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-81689 Sidetrack No, 1 Page 2 of 2 I~ Company ARCO ALASKA, lNG, Rig Contractor & No. PARKER DRILLING CO. - #245. Field KUPARUK R~/ER U~NIT Well Name & No. 2F-PAD/2F#18(GH) Survey Section Name SPERRY SUN BHI Rep, _ _ i ~'J~r~~ , WELL DATA '/~' Target'i'VD (FT) Target Coord. N/S Slot Coord. N/S -275.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLJ--] SS~ Target Description Target Coord. EJW Slot Coord. F__./W -1713.00 Magn. Declination 27.1~0 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: lOOft~ 30m~ lOmr-] Vert. Sec. Azim. 171,49 Magn. to Map Corr. 27.860 Map North to: OTHER ......... sURVEY ............. DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Anglo Direction Length TVD Section N(+) / $(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT~ (DD) (DD) (FT) !FT) (FT) (F'I') (Per 100 F'l') Drop (-) Left (-) 15-JAN-97 MWD 9641.69 25.42 169.42 256.73 6318.61 6357.30 -6267,06 1076.04 0.67 -0.57 0.80 -, 16-JAN-97 MWD 9715.00 25.42 169.42 73.31 6384.83 6388.75 -6298.00 1081.82 0.00 0.00 0.00 PROJ TD*BHC=6390'@ 170.25deg. .,-- ., -- ., _ -- ,._ .., - 96 .... 'i'78 CE',L ~/'~800 .... 9575 ,..F~/,SONPLETZON DATE ~/)~ /~7/ DAILY WELL OPS ,.,lq: 12. i'~..~ /'~G / l',S, ) /'1~{ /"~?,/' ~- /')'~/q'2/" We 'l i ri I:! ILl__ I IM G S E I::t ~./I I-- I~ S WELL LOG TRANSM1Tr~ To: State of Alaska April 30, 1997 Alaska Oil and Gas Conservation Comm. 3001 Porcupine Dr. ~ Anchorage, Alaska 99501 ~ ~ MWD Formation Evaluation Logs DS 2F-18 & 2F-18 PB1, AK-MM-60201 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22720-00 & 50-029-22720-70 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company CI I:::! I I--I-- I rli G S I::: I::! ~J I C ~:: S WELL LOG TRANSMITTAL To: State of Alaska April 23, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. /'! ~ Anchorage, Alaska 99501 ~il ~9,2 MWD Formation Evaluation Logs DS 2F-18, 2F-18 PB1 RE: AK-MM-60201 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 2F-18: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22720-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22720-00 1 Blueline 1 Folded Sepia DS 2F-18 PBI: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22720-70 1 Blueline 1 Folded Sepia 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22720-70 1 Blueline 1 Folded Sepia DS 2F-18 PBI: 2"x 5" MD Neutron, Density & Gamma Ray Logs: 50-029-22720-70 1 Blueline 1 Folded Sepia 2" x 5" TVD Neutron, Density & Gamma Ray Logs: 50-029-22720-70 1 Blueline 1 Folded Sepia .2.~ ~ ~ ~?~, ~:~ '~ ,,~~'~ { 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 , Fax (907) 563-7252 A Dresser Industries, Inc. Company 3/12/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10857 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk (Reservoir Analysis Logs) RF Sepia Floppy Disk 1Y-02 -~;~- C)~'~ WATER FLOW LOG-TDTP 970222 I 1 1Y-08 -~- O(z;~Z-. INJECTION PROFILE LOG 970218 I 1 2F-18 c~L~. ,I-~ CEMENT BOND LOG 970207 I 1 31-12 '-~G ' ©G© PRODUCTION PROFILE 970218 I 1 3N-04 -~. C>~ INJECTION PROFILE LOG 970202 I 1 3N-09 '~(o ' O~:~ PRODUCTION PROFILELOG 970204 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: I'1 F! I I_1_ I I~1 G February 27, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 2F- 18 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 2F-18 MWD survey Tie-In point at 0.00', Window Point at 5,700.00' and a Projected survey at 9,715.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino. Company February 27, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 2F-18 PB1 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 2F-18 PB1 Tie in point 0.00', interpolated depth at 9,591.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. REC ~AR 0 5 1997 ~ 0fl & G~ Cons. ~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 2/6/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10775 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 2F-18 ~(,.o-t-7~ t:t_ ?~/.-~,. 97037 LDT/CNL 970116 1 2 F- 18 .'] COMP NEUTRON-LITHODENSITY 970116 1 1 2 F- 18~ LDTD-CNTG-SGTL 97011 6 I I SIGNED: ~___~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CC)MMIL~51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing _ Repair well _ Plugging __ Time extension _ Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, I.nc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1138' FNL, 672' FEL, Sec 4, T10N, R9E, UM (approximate planned) At effective depth At total depth 1298' FNL, 705' FEL, Sec. 4, T10N, R9E, UM (approximate planned) 12. Present well condition summary Total Depth: measured 5941 feet Plugs (measured) (approx) true vertical 6. Datum elevation (DF or KB) RKB 41', Pad 97' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-18 9. Permit number 96-178 10. APl number 50-029-22720 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 3245 feet Top of kickoff plug in preparation for sidetrack Effective depth: measured (approx) true vertical 5941 feet Junk (measured) 3245 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented '80' 16" 200 sx CF 5574' 9-5/8" 330 sx ASIII, 1220 sx G, 60 sx AS I measured None Measured depth True vertical depth 121' 121' 5615' 3124' true vertical Tubing (size, gmde, and measured depth) None Packe~ and SSSV (~pe and measured depth) None jAN 1997 A~aska Oil 8, Gas Cons, Commission Anct~orage 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch 14. Estimated date for commencing operation 1/17/97 16. If proposal was verbally approved Name of approver Date approved S e rvi c e 17. I hereby certify that(~e 727 is true and correct to the best of my knowledge. Signed , ~, Title Drill Site Dev. Supv. d,,/'" '~, FOR COMMISSION USE ONLY Conditions of approval: Notify ~om~j~_!ssion so representative may witness Plug integrity BOP Test_ Location clearance Mechanical Integrity Test _ 15. Status of well classification as: Oil X Gas __ Suspended Date (--- t ~ ""~O Approved by the order of the Commission I Approval Subsequent form r~quire lO- Original Signed By [:)avid W. Johnston Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Approved Copy KRU 2F-18 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 2F-18 for basic details on the cementing operation. Additional information is offered below in support of ARCO Alaska Inc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25.030). Surface Hole TD: 5632' MD / 3131' TVD Surface H01e Conditions: Some packing off was seen when drilling near the top of the West Sak, but frequent sweeps to improve hole cleaning seemed to address the problem. Further drilling and tripping operations were without incident. A shallow section drilled at 1096' MD realeased minor amounts of oil in the mud but was not seen during subsequent operations. Casing was run to bottom without problems, with precautionary circulation occurring at 2116' and 4086'. No fill was seen on bottom. Full returns were seen at all times. The hole was TD'd with 9.6 ppg mud. Stage Tool Placement: 2F-18 was cemented as a two stage job using Halliburton's Type H ES Cementer placed at the base permafrost (1525' MD). Casing Placement: The casing was reciprocated until cement rounded the shoe and movement became difficult. The pipe was completely free prior to this point. The surface casing shoe was placed at 5615' MD, 17' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Full returns were seen while circulating on bottom prior to cementing (8 bpm) and during the start of the cementing operation itself (8 bpm). Returns were completely lost with 223 of 250 bbls slury outside the casing. Cement contaminated mud was circulated out after shifting open the ES Cementer. Full returns were seen during the second stage of the job. 10.5 ppg cement (the pumped weight of the new lightweight slurry) was seen at surface prior to dropping the plug and shifting the Cementer closed. Excess on the first stage lead cement was 45%, with 35% on the tail cement. The second stage lead was pumped until cement came to surface. The first stage excess factors were based on historical data (3A-17 surface hole bond log) and surface hole caliper logs performed at Milne Point, and were very conservatively calculated with the intent of bringing tail cement to 500' above the top of West Sak. Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. ARCO Alaska, Inc. · Well#: 2F-18 Casing Size 9 5/8" Centralizers Mud · Spacer Lead Cement STAGE 1/2 Tail Cement STAGE 1/2 Displacement Hole Diameter 12.25" Field: KUPARUK Hole'Ang!e I . Shoe Depth 70° 'I 5,615' Cementin~ Details Date: 1 2/25/96 Float Depth I % washout 5,482' I State type used, intervals covered and spacing 102 Gemco centralizers.l-4 = 2 per jt 5-27 (odd) 1 per jt 6-28 (even) 2 per jt 29-84 1 per jt I on each side of cementer Weight 9.8/9.7 Gels before 1 5/26 Type Water YP. (prior cond) 38 lbs/100 It2 Gels after' 8/15 Type I Mix wtr temp ASLW I 6 0 YP(affer cond) I PV(prior cond) 21 lbs/100 ft21 28 cP Total Volume Circulated 2 bbls Volume 4O/2O No. of sacks 55/275 Weight 1 0.5/1 0.5 PV(after cond) 22 cP Weight 8.3 PPG Yield 4.41 Additives G + 3.5% DO44, .6% DO46, 30% D53, 1.5% DO79, 50% D124, 1.5% SOO1 Type IMixwatertempl Ne. of sacks I Weight1 Yield G/AS 1 60 1220/60 15.8/15.8 1.15/0.93 STAGE 1' G , 2.66% DO29, .2% DO46, .3% DO65, 1% SOO1 STAGE 2: ASI Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 8 8 Str. Wt. Dn. Reciprocation length 15 Reciprocation speed 10 fpm Actual Displacement 421/120 Bumped plug J FIoats held yes/yesI yes/yes Theoretical Displacement 416/1 16 STAGE 1/2 Calculated top of cement 2500'/surface CIP 11/26/96 04:30 / 07:15 Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage 1' Reciprocated csg until cement rounded :shoe. Became sticky. Circ 650 bbls mud w/no loss. Pumped lead and'tail slurries. Displaced w/rig pumps. Str. Wt. Mud Had 100% returns until 346 bbls Of displacement pump. Lost all returns. Had 223 bbls cement ,outside csg, est!TOC at 2500'. Bumped plug Stage 2: Press csg to 2700 psi to open cementer. Circ 400 bbls mud w/full returns. Had contaminated returns at bottoms up. Pumped 2nd stage lead and tail slurries w/ 100% returns through out entire job. Had cement to surface w/216 bbls lead pumped. Switched to tail slurry. Displaced w/ rig pumps. Closed cementer w/ 1200 psi. Cement Company I Rig Contractor Dowell I Parker Signature Donald Lutrick CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 2F-18 Date: 12/26/96 Supervisor: Donald Lutrick Casing Size and Description: Casing Setting Depth: Mud Weight: 8.6 9 5/8", 40#, L-80, BTC 561 5 TMD 3125' TVD ppg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT = 660 psi / (0.052 x 3134 ft) + 8.4 ppg = 12.45 ppg Hole Depth (md)= 10,246 Fluid pumped = 1.2 bbls. Pump output = .101 bps 2100 2000 19 o o ,[,:~ - - - 1800 1700 1600 1500 1400 - 1300 1200 ' oo 1000 900 .:.;. 800 800 400 300 2 . 200 ./J~ff + LI=AK-OFF 1181 ~:~ ~ CASING TEST,, ot ' ARCO Alaska, Inc. Post Office 8o× 100360 Anchorage, Alaska 995i0~0380 Telephone 907 278 12!5 January 7, 1997 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive ]'~,~l~l V ~,~ Anchorage, AK 99501 JAN '] 4 1997 Subject: Az'mu_tar Pumping Approval for :F_AU Well f~~l & Gas Cons. Comm~ion Dear Mr. Johnston: ,~orage Kuparuk River Unit Well 2F-18 was permitted to drill in November, 1996. The permit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOGCC. We believe that the 2F-18 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. If you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Si erely, Drill Site...~evelopment Supervisor AR3B-6003-93 242 2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well Plugging __ Time extension Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5, Type of Well: 6, Datum elevation (DF or KB) Development _ ARCO Alaska, It~¢. Exploratory X RKB 41', Pad 97' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. BOX 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM 2F-18 Gold HilJs At top of productive interval 9. Permit number 1244' FNL, 778' FEL, Sec 4, T10N, R9E, UM 96-1 78 At effective depth 10. APl number 50-029-22720 At total depth 11. Field/Pool Kupurak River Field/ 1244' FNL, 778' FEL, Sec. 4, T10N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 971 0' feet Plugs (measured) (approx) true vertical 6197' feet Effective depth: measured feet Junk(measured) (approx) true vertical 6326' feet "T-o~ ~Drill pipe Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 200 sx 1 21 ' 1 21 ' Surface ,'15' 5/'" l ,lo ' Intermediate ~ ~" ~ D ~1 ~..,~ Production Liner Perforation depth: measured JAN ] 0 7997 None true vertiCal .~aS~3 0il & (~a$ C0rl$, COIlllTIjS~Jori A~ch0rage Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal__ Detailed operation program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: Oil X Gas __ Suspended 16. If proposal was vertj~lly ~apFo~ved .11, _. th (1 Name of approver ~ ~J~ OO~. [( /~a~ a~p~oved Service 17. I her~ .~y certify that the foregoing is t~e and correct to the best of my knowledge. Signed ~.._ if~V~(O~ IF'L~. c~ ~Title Senior Drillin~ E~ineer Date FOR ~MMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No~ Plug integrity ~ BOP Test_ Location clearance__ I Mechanical Integrity Test _ Subsequent form require 10- ~o~ 0ng~nal Signed By Approved bY the order of the Commission ~av~d W, J0hRs[~ commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Approved Copy Returned 3'l;2_-6q9-z06'~II 3300 0,.55 ~,'?. - eM/-<', 4 / MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Joh]:~~ Chairman----'~ Blair Wondzell, P. I. Supervisor DATE: FILE NO: January 7, 1997 abxhaged.doc Confidential: Yes Attachment Only _, NoX, · FROM: Doug Amos, ~-~% ~~-~--SUBJECT: Petroleum Inspector BOPE Test Parker Rig 245 KRU 2F-18 PTD 96-0178 Tuesday, January 7, 1997: I traveled to Arco's KRU 2F-18 well, to witness the BOPE test on Parker Rig 245. The drilling permit on location indicated that this should have been a'5,000 psi BOPE test but the 9 5/8" casing head flange was rated at 3,000 psi therefore we tested the 5,000 psi stack and related equipment to 3.000 psi. According to the morning report the initial 9 5/8" casing BOPE test, performed on 12/25/96, was 5,000 psi. Further investigation revealed that the well plan called for installing a 5, 000 psi adapter to the 9 5/8" casing spool after the 7" casing was run and cemented and then testing the stack to 5,000 psi. Guy told me that steps were being taken to ensure this situation was not repeated in the future. As the attached AOGCC BOPE Test Report indicates/there was one failure. The choke manifold had to be flushed several time to remove LCM from the valve bodies and seats before the valves would pass this test. Choke Manifold Valve #11 failed, it was rebuilt and retested before drilling out. I found the location clean and well organized, the rig clean and all equipment in compliance. SUMMARY: I witnessed the successful BOPE Test at Arco's KRU 2F-18 well on Parker Rig 245. 5.0 Test Hours 23 Valves Tested One Failure Attachment: ABXHAGED.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: .. Parker Drilling Co. Rig No.~ Operator: Arco Alaska Inc. Well Name: KRU 2F-18 Casing Size: 9 5/8" Set @ 5, 614 Test: Initial X Weekly Other DATE: 1/7/97 245 PTD # 96-0178 Rig Ph.# 659-7670 Rep.: Guy Whitlock Rig Rep.: Fred Hergert Location: Sec. 33 ?, '/1 N R. 9 E Meridian Umiat ,,, Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign Yes Drl. Rig OK Hazard Sec. Yes FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP 1 Ball Type 1 Inside BOP 1 Quan. Pressure P/F '/ 250/3,000 P P 250/3, 000 250/3,000 P P 250/3, 000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 1 250/3,000 '/ 250/3,000 1 250/3, 000 1 250/3,000 1 250/3,000 I 250/3,000 2 250/3,000 N/A 250/3, 000 P/F P P P P P N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves '/6 No. Flanges 38 , , Manual Chokes 2 , , Hydraulic Chokes 1 Test Pressure 250/3, 000 250/3, 000 Functioned Functioned P/F P/F P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 @ 2, 35o 3, 000 P 1,700 P minutes 26 sec. minutes 16 sec. Yes Remote: Yes Psig. Equipment will be made within /V/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC 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 I REMARKS: Choke Manifold valve 11 failed, the valve was rebuilt and retested before drilling out. All choke manifold leaked on initial tests but after washing the LCM out of the seats and bodies all vavles except '/1 passed their tests. Distribution: orig-Well File c - Oper.tRig c - Database c - Trip Rpt File c - Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Doug Amos ABXHAGED.XLS STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well _ Plugging __ Time extension_ Stimulate __ Change approved program ..X_X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 275' FNL, 1713' FEL, Sec. 33,-T11N, R9E, UM At top of productive interval 5. Type of Well: Development _.X_ Exploratory __ Stratigraphic _ Service 6. Datum elevation (DF or KB) 1138' FNL, 672' FEL, Sec 4, T10N, R9E, UM (approximate planned) At effective depth At total depth 1298' FNL, 705' FEL, Sec. 4, T10N, R9E, UM (approximate planned) 12. Present well condition summary Total Depth: measured 9710 feet Plugs (measured) (approx) true vertical 61 97 feet RKB 41', Pad 97' 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-18 9. Permit number 96-178 10. APl number 50-029-22720 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical 5941 3245 feet Junk (measured) feet Drill pipe fish at 6326' Casing Length Size Cemented Measured depth Structural Conductor 8 0' 1 6" 200 sx CF 1 21 ' Surface 5574' 9-5/8" 330 sx ASIII, 1220 sx G, Intermediate 60 sx AS I Production Liner Perforation depth: ~;ured . ,~.,~,~--,~0 true vertical Tubing (size, grade, and measured depth~Non~ an. ea,ur None True vertical depth 121' 5615' 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch 14. Estimated date for commencing operation 1/7/97 16. If proposal was verbally approved Name of approver Blair Wondzell Date approved 1/6/97 15. Status of well classification as: Oil X Gas __ Service Suspended 7. I heLebv ced. if~ that the foregoing Sic~ned is true and correct to the best of my knowledge. Title Drilling Engineer -- FOR COMMISSION USE ONLY Date 1/7/97 Conditions of approval: Notify Commission so representative may witness Plug integrity ~-.__.~ BOP Test ~"~'Location clearance__ Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission David W .~0hast0rl 10- /.¢~? Commissioner Form 10-403 Rev 06/15/88 IApproval No. _ Date SUBMIT IN TRIPLICATE P..pproved Copy Returned _ KRU 2F-18 Proposal Description Well 2F-18 "Gol~lhill" was originally intended as an exploration well for prospects below the Kuparuk formation. However, higher than expected reservoir pressures were encountered when drilling through the Kuparuk. Lost circulation occurred in the process of weighting up the mud. Losses were severe enough to require the well to be P&A'd (addressed in a separate Sundry Application). The open-ended drillpipe work ~,~ string was cemented in place during the abandonment, leaving a top of fish at 6326' MD. At this point Parker Rig 245 is preparing a kick-off plug at the existing surface casing shoe. ARCO Alaska, Inc., proposes to sidetrack at +5700' MD around the junk to a target location approximately 150' to the NE of the existing permitted target. Due to the high reservoir pressures, the Kuparuk formation will be topset with a 7" 26~ L-80 intermediate casing string. Parker 245 will drill 10' of new formation and perform a FIT to a maximum 14.0 ppg EMW. A 6-1/8" hole will be drilled through the Kuparuk to TD, and a 5" 18# L-80 LTC liner run. The liner-top assembly will consist of a liner-top packer, hanger and PBR. The PBR will replace the completion packer. Parker 245 will run and test the 3-1/2" KRU completion string prior to leaving the well ready for cleanout and perforations in the Kuparuk. Setting the intermediate string above the Kuparuk, and the high Kuparuk reservoir pressures, effectively eliminate the opportunity to continue drilling to the deeper exploration targets as originally proposed. 2F-18 will be drilled and completed solely as a Kuparuk development well and will be reported that way from this point on. ARCO ALASKA, Inc. Sfrucfure: Pad 2F' Well : 18(GH) Field : Kuporuk River Unif Location : Norfh ";lope, Aleska 600 Easf (feel) -> 700 800 go0 1000 Created by jan~ D~te I~lot-[ed: 7-J~3n-g7 PIo~ R~e~ ;s 2F--lB ~ V~ ~1. ~rd~t~ ere in feet rd~e a~ ~18. [~ Yeff~;l Depths ~e r~e~e RKB (P~ ~245) --- ~ker Hu~he~ IHTEQ --- 2800 3O00 3200 3400 3600 3800 4000 4200 =,1-- ~.. 4400 0 4600 0 ,,-- 4800 5ooo k_ I V 5200 5400 5600 5800 6000 6200 6400 3800 g 5/8 Casing 63,69 61.19 58.6g 56.19 53.69 51.19 48.69 46.1g DLS: 2.50 deg per 100 ft 45.6g 41.19 38.69 36.20 '~,,~,. 33.70 31.20 "~,~,. 28.70 26.20 ~,~, · · lot§et - 25.63 In¢, 926g.~5 Md, 5964.00 Tvd, 617g.33 Vs T.D. & End of Hold - 25.63 Inc, 9648.53 Md, 6306.31 Tvd, 6543.35 Vs i i i 4000 4200 i i i[ i i i i i i ii i ii i ii i i 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 Vert[col Section (feet) -> Azimufh 171.49 wifh reference 0.00 N, 0.00 E from sial i i i i 6400 6600 1100 1200 5O0O 5100 5200 5300 54OO 5500 5600 5700 58OO 5900 6O0O 6100 62OO 63O0 640O 0 ARCO Alaska, Inc Daily Drilling Reports AFC NO I Date Rpt No Rig Accept - hr$ Est Accept Day~ Rig -'-"-~ - AX93 74I 1~/~0/96 I Accpt ' Previous Depth MD Progre-- W'~ 2 F- 1 8 - Depth (MD/TVD)121 / 121 121 · Daily Cost ' Cum Cost Est Cost To Date 71000 Contractor PARKER 245 85966 85966 Operafi~ At 0600 -. Last Csg Next Csg 9 5/8" @ 5635' Shoe Test M.O.V_~GRIG 16" @ 121' ..... N/A -.-- MUD DATA DRILUNG DATA BIT DATA EH&S DRILLS / BOP DATA INCIDENT (Y N) LAsT BOP/DIVERT TST LAST BOP/DRILL uuD ~'~P~ oE~r, aT ~O 1 N 11117/96 1022/96 WE.~HT ~OT v~r s;= 121/4" EMPLOYER ~ST H2S DRILL LAST FIRE DRILL pm sP~0, N) 'N f ~,~ 1(Y17/96 VlSCosrr~ PU~ ~ STC ~ 7'fl=E LAS'~ CONFINED SPACE LAST SPILL DRILL Pw~P sovw wP~ MAli SL VOLUME . , .'.~.~J6 9~12/96 oa.s Av~ D;~. s~,~..o ' ;~ ' · . '~sl' ~ ~,,X~ DE"'r. OU'r ./ s~m'~e 2/20FJ6 FUEL & WATER FUEL USED "~,, w, T~ ~u ~H a INJECTION 2747 TWO rn~ 121 sOUDS TRQ OFF FOOTAGE INJECTION WELL DRILL WATER USED-BBLS % 8OURCE WELL 0 i HOLE VOLUME PU~ PRES AOT/AS~ POTABLE WATER USED'BBLS ~u 2100 ~TE (~o.,) 240 u~r ~UM~ 1 2 mU [: WEATHER & PERSONNEL DATA ph ,,.~ .~ 6 6 =ES~LVOL(t~) 0 TEMPERATURE, °F LGS JETSTFA % seta~ MUDVOL(U~ 0 WIND SPEED'KTS 10'15 E PIT VOL aT C,O~T bl~ GPM 2 13Z~0 WATER VOL (bb0 0 CHILL FACTOR, °F -40 TOTAL MUD $.g:;~; SPP 1 GRADEI J I I TOT FOR WELL (bbl) (~ MISC PERSONNEL 15 ' MUD w'r TOTAL ~W~;; 47 BHA DESCRIPTION BH~ NO 1 OD WlEGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH DATE LAST INSPECTED:. HOURS ON JARS 24:00 OPE 00:00 24:00 3:00 24:OO PREPARE TO MOVE RIG. MOVE CAMP AND AUXILIARY MODULES TO DS 2F. CAMP IN PLACE AT 13:00 HRS. START MOVING RIG MODULES. DRILLING MODULE MOVED 6.6 MI FROM DS lC AND UTILITY MODULE MOVED 7.8 MI FRC~M ~R-I~ TCiTAI i:i1~ MC)VIc TC) RI:: 1~ R MI Supervi~or G.R. WHITLOCK ARCO Alaska, Inc Dally Drilling Reports AFC NO I Dato Rpt No I Rig Accept-hrs Est Accept Rig Retea~e-hra AX9374 12/21/96 2 12f21/96 17:00 Accpt 26 Previous Depth MD Progress Wo, 2F-1 8 - Depth (MD/TVD)121 / 121 121 0 Contractor PARKER 245 DailyCost ~ ~- Cum Cost Est Co~t To Date 85966 171932 71000 operation At 0600 -. Last Csg Next Csg Shoe Test MAJ RHA 16' @ 121' 9 5/~' @ 5635' ..- N/A MUD DATA DRILMNG DATA BIT DATA EH&S DRILLS / BOP DATA MUDTYPE SPUD DE.T. ;aT NO I INCIDENT C~ ") N LAST BoP/DIVERT TST LAST BOP/DRILL ~OTWT i S~ 12 1/4" ~U~OYE~ 11/17/96 lg22/96 WEt~3HT 8.5 ma ~-~T H2S DRILL LAST FIRE DRILL wscosm, 45 .,, :.uw'r ~ STC a,~(Y,) N ~ ~'t(V9/96 1~17/96 ~ LAsT CONFINED SPACE LAST SPILL DRILL ~/~ 12/10 so w~ T~ MA1SL . iGELS 2/5 AVGI DRN3.. sERIALNo VOLUME ' 't · 9/6/96 af12.J96 ^P~w~ 20 MAXD~A~ DEm'Ho~r ~, SAFCrY~T<~ 12/21/96 FUEL & WATER HTHP WL TI=IQ s'rM DEmHa INJECTION FUEL USED mV30 n~n 121 3087 · OUD~ 2 ~/e ~ OFF FOOTAGE INJECTION WELL I DRILL WATER USED-BBLS '" HOLE VOLU~E .JM..RES A~r/A~ SOURCE WELL 2F.18I 0 b~ 2100 POTABLE WATER USED-BBLS ~:)B 2 RATE (bl3m) 12D ~r 20 PuM. 1 2 ~:~ NO PRESSURE .h 8 u.~ m 6 6 R~M i WEATHER & PERSONNEL DATA D~ESEL VOL L(~S JETSTFA 0 TEMPERATURE, °F +10 2 % ~,tt MUD VOL (IN:d) 0 WIND sPEED'KTs 12'15 SW ~r vol 400 bU ~PU 2 ~r COST 134~0 WATER VOL (bl~) 0 CHILL FACTOR,°F -20 TOTAL MUD $2~6 SI==P I GRADE TOT FOR WELL 0:~bl) ~ MISC PERSONNEL 17 ... MUD WT 8.5 TOTAL BHA DESCRIPTION , I~H~ NO D~LU'~P{ O~TA (TOP TO SOT'rOM) 1 OD WlEGHT GRADE. CONNECTION CLASS 2 LENGTH BHA LENGTH -I~ATE LAST INSPECTED: ~I~URS ON JARS T1ME OPERATIONS FROM 0000 · 0000 00:00 10:30 17:00 24:00 10:30 17:00 24:00 MOVE DRILLING MODULE AND UTILITY MODULES ONTO DS-2F. POSITION RIG OVER HOLE-CONNECT MODULES ACCEPT RIG AT 17:00 HRS 12/21/96. NAJ DIVERTER SYSTEM, ADJUST L/D MACHINE, START PAJ D.P. Supervisor G.R. WHITLOCK 2 F-1 8: IContractor PAR KER Operation At 0600 12/ppl96 ARCO Alaska, Inc I Rig Accept - hrs Rpt No 3 12/21/96 17:00 Depth (MD/TVD?845 .. / . 1660 245 Daily Cost 91565 -. Last Csg 16" @ 121' MUD DATA DRILUNG DATA MUD TYPE DEPTH .SPUD 1845 ~WEK~ 9~3 .OTW~ 145 67 150' 130 GELS ~ AVG DRAG. HTHP WL TRQ BTM rnmOr~ 4 ;souPs 2 % TRQ OFF 4 HOLE VOLUME PUM= PRES 250 2250 BIT DATA 1 121/4" STC MAISL LJ1626 121 1724 &05/5.94 35/4O 7O Daily Est Accept ~ Days 15I Accpt 1~6 Previous Dep~ MD 121 Cum Cost 263497 Next Csg 9 5/8" @ 5635' Drilling Rig Release - hm Progress Est Cost To Date Reports 1724 250000 Shoe Test - ' N/A EH&S ~.C~DENT ~' N) N EMPLOYER ~,.L (Y N) N TYPE VOLUME INJECTION ,~.~cnoN WELL 2M-23 sou.ce w~LL 2F-18 RATE (bra) 5 DRILLS I BOP DATA LAST BOP/DRILL 1(722)96 LAST BOP/DIVERT TST 11/22/96 · ;LAST H2~ DRILL LAST CONFINED SPACE LAST FIRE DRILL 10/17/96 LAST SPILL DRILL FUEL & WATER FUEL USED 4310 DRILL ~/ATER USED-BBLS 1500 POTABLE WATER USED-BBL$ 225 ph LGS $.7 % PrrvoL DALLY MUD $ 6108 TOTAL MUD $8552 BHA DESCRIPTION 13460 mESSURE (~) 850-975 DIESEL VOL (1~ 505 MUD VOL (b~) l(XX) WATER VOL (bbl) 18.75 TOTAL VOL (biN) 1069 TOT FOR WELL (t~) 10~9 120 WEATHER & PERSONNEL DATA TEMPERATURE, °F +-2 WIND SPEED-KTS 6 SE CHILL FACTOR, °F -10 CONTRACTOR PERSONNEL 30 MISC PERSONNEL 18 TOTAL 48 Bit, Navidrill-l.2, nmstab, nmdc, nmstab, mwd, ubho, 3.nmdc, 3-dc xo, 4-hwdp, jars, 25-hwdp BHA NO . IpRII~PIPI~ pAT~, (TOP T9 BOTTOM) '~ OD WIEGHT GRADE CONNECTION Bt-lA LENGTH 1181~. DATE LAST INSPECTED; HOUR~ ON JARS 8.1 TIME OPERATIONS FROM 0000 . 0000 CI. ASs 2 LENGTH 00:00 04:30 04:30 05:00 05:00 07:30 07:30 14:00 14:00 16:3'0 16:30 22:00 22:00 22:30 22:30 24:00 24:00 PAJ 53 STANDS 5" D.P, FUNCTION TEST DIVERTER, TEST KOOMEY, FILL HOLE PAJ BHA AND ORIENT DRILL 121' TO 724' ADT=3,87 HRS, MWD FAILED, POOH, DOWNLOAD MWD, CHANGEOUT MWD & PROGRAM, ORIENT TOOLS, AND RIH DRILL 724' TO 1644' ADT= 3.$3 HRS, HAD OIL AND SAND AT SHAKERS O 1096' SERVICE RIG DRILL 1644' TO 1845' ADT= .6 HRS Supervisor G.R. WHITLOCK ARCO Alaska, Inc Daily Drilling Reports AFCNO tDa~e RptNo I Rig Accept-hrs Est Accept I Days Rig Release - hrs AX9374 1~/~3/g6 4 12/21/96 17:00 3J3 Accpt 226 Well 2 F- 1 8 - Depth (MD/TVD~I Previous Depth MD Progress 43 / ... 2961 1~45 329~ Contractor PAR KER 245 Daily Cost 84661 Cum Cost 34~15~ Est Cost To Date 400000 'Operation At 0600 -. Last Csg Next Csg Shoe Te~t SHORTTRIP 16" @ 121' 95/8" @ 5635' .-' N/A · MUD DATA DRILMNG DATA BIT DATA EH&S DRILLS"/BOP DATA MuDTY~ SPUD OF.~r, 5143 BiTNO 1 INCIDENT (Y N) N LAST BOP/DIVERT TST LAST BOP/DRILL ~OT WT aZ~ ea=~OY~ 11/22/96 10'22/96 WEIOHT 9.6 m3 140 12 1/4" 'l.~sm H2S DRILL L~ST FIRE DRILL ~/iscosrn' 66 ,uwr 155 ~ STc a,,.L(Y,) N ~ ~i 1/23/96 10/17/96 ,v/~ 22/26 so wr 110 w~E" MA1 SL LAST CONFINED SPACE LAST SPILL DRILL VOLUME - 't ' . 9/6/96 ~12/cJ6 GELS 12/28 AVG ORAG.. S~.~AL ,O LJ1626 J . LAST '~',~WL 7.4 ~XDRAG DEPTH OUT .,/ SA~ETY~rG 12J23/96 FUEL & WATER - NTH. WL TF~ BTM OaTH ~ iNJECTIoN FUEL USED mv3o rr~n 8 121 . 5226 = INJECTION WELL ~;3UDS 9 % T~O~r 7 ir~°TAc'E '5022 2M-23 DRILL WATER USED-BBLS 2100 Pu~PP~s ~T/A~ soURCE WELL 2F-lB POTABLE WATER USED-BBLS H0~ VOLU~ 723 ~ 2700 ~a, 1 3 WO~ ~ ~T= (~) 5 130 MB3' 2~ pJ~b NO 3(~J~ PRE$StJRE (p~) 850'975 ~h ~'M~ WEATHER & PERSONNEL DATA -~ 8.5 =,~ .~ 6 6 75 aES~LVOL(~) LGS JE'rsTFA 0 TEMPERATURE, °F 8.5 % s~ 85 85 1'10, 2'15 MUO VOL(t~) 1740 WiND SPEED-ETS 13 SW PITVOL 500 b~ GPM2 3~1 3~ Bfl'COST 134~0 WATER VOL (bb0 0 CHILL FACTOR, °F -25 DAILYMUD$ 12404 S~S! DULL I TOTAL VOL(~) 1740 CONTRA~TORPERSONNEL 30 TOTAL MUD $20~;~ S~P ! GRADEI TOT FOR WELL (t~) 2~09 MISC PERSONNEL 20 . . MUD W~ 9.6 9.6 TOTAL '~HA DESCRIPTION Bit, Navidrill-l.2, nmstab, nmdc, nmstab, mWd, ubho, 3-nmdc, 3-dc, xo, 4-hwdp, jars, 25-hwdp BHA NO O~LLmPE 0ATA (TOP'T° BOTTOM) . '1 OD WIEGHT GRADE CONNECTION CLASS 2 LENGTH 1181~. DATE LAST INSPECTED: HOURS ON JARS 00:00 08:30 08:30 1 0:00 10:00 12:30 12:30 13:00 13:00 14:0~) 14:00 19:00 19:00 19:30 19:30 24:00 24:00 OPERATIONS FROM 0000 · 0000 DRILL 1845'-3420' ADT= 4.8 HRS . HOLE PACKING OFF. CIRC/COND MUD. PUMP 50 BBL LOW/50 BBL HI VIS SWEEP. SHORT TRIP TO HWDP. RIH. SERV~E RIG. DRILL 3421' - 4449' ADT= 4.2 HRS, ClRC 50 BBL LOW/50 BBL HI VIS SWEEP DRILL 4449' TO 5143' ADT= 3.24 HRS Supervisor G.R. WHITLOCK ARCO Alaska, IRpt No Inc Rig Accept - hra 12J21FJ6 17:00 wo, 2 F- 1 8: Contractor PARKER 245 Operation At 0600 ~ CEMENT ~ 5/8" CSG rDepth (MD/TVD~632 / Daily Cost Last Csg -' 3131 75163 .16' @ 121' Daily Drilling Reports Est Accept ~ Days 4.0 ~ Accpt ~ Previous Deplh MD ~;143 Cum Cost 423321 Next Csg 9 5/8" @ 5635' Rig Release - hrs Progress Est Cost To Date 4Bg 550000 Shoe Te~t · '-' N/A MUD DATA DRILUNG DATA MUD TYPE DEPTH SPUD · 5143 9~ .OT ~ 140 puwr 155 110 Ga.s 12/28 Ave DRAe- ~[WL 5.5 kt~X c~o HTHP WL T~ ~ ~ 8 HO~ VO~ME ~ p~ 77O ~ LGS ~ % ~ VOL DAILY MUD $ 3112 TOTAL MUD s2~ BIT DATA 1 121/4" STC MAISL LJ1626 5632 121 5511 1346O EH&S INCIDENT (Y N) N ':MPLOYER S~LLC,' N) N VOLUME INJECTION ~.~CT]ON WEU. 2M-23 SOURCE W~U. 2F-18 RATE (bi=m) 5 mEaSURE (p.) 850-975 (~ESEL VOL (b/~) ~ MUD VOL (b~) 1575 WATER VOL (~) 0 TOTAL VOL (~ 1~ TOT FOR WE~ (~) ~ DRILLS ! BOP DATA LAST BOP/DIVERTTST J LAST BOP/DRILL 'LAST,~I2~" DRILL LAST FIRE DRILL ,' tl/23/96 12/01/96 LAST CONFINED SPACE LAST SPILL DRILL :~' 12/03/96 12/1G,~J6 FUEL & WATER FUEL USED ~Clll I WATER USED-BBLS POTABLE WATER USED-BBLS 120 WEATHER & PERSONNEL DATA TEMPERATURE, °F 4 WIND SPEED-KTS 9 CHILL FACTOR. °F -12 CONTRACTOR PERSONNEL 31 MISC PERSONNEL 19 TOTAL ~0 BHA DESCRIPTION Bit, Navidrill-l.2, nmstab, nmdc, nmstab, mwd, ubho, 3-nmdc, 3-dc, xo, 4-hwdp, jars, 25-hwdp 8HA NO 1 OD WIEGHT GRADE BHA LENGTH 11812 DATE LAST INSPECTED: HOURS ON JAR8 00:00 03:00 03:00 04:30 04:30 09:00 DFIILLPIPE DATA (TOP TO BOTTOM) OPERATIONS FROM 0000 - 0000 DRLG F/5143' TO 5632'. ADT - 2.2 HRS ClRC AND PUMP LO/HI VIS SWEEP. PUMP PILL. WIPER TRIP TO HWDP. NO PROBLEMS. 09:00 10:30 10:30 14:00 14:00 15:00 15:00 16:00 16:00 19:30 19:30 20:00 20:00 22:00 22:00 23:00 23:00 24:00 24:00 CIRC AND PUMP LO/HI VIS SWEEP. PUMP PILL. POH LD BHA. NO PROBLEMS. CUT AND SLIP DRLG LINE. RU GBR. HELD PREJOB SAFETY MEETING. RIH W/9 5/8' CSG TO 2116'. CIRC AND CONDITION MUD. RIH W/9 5/8' CSG TO 4086'. ClRC AND CONDITION MUD. MU ES CEMENTER. RIH W/9 5/8' CSG. Supe~isor Donald Lutrick IAFC NO I Date AX9374 I 1~/'~/96 we" 2F.18: IContractor PARKER 245 Operation At'0600 ' -. DRILL ES C --MENTER ARCO Alaska, Inc Rpt No _ I Rig Accept- hrs 6 I 12./21/96 17:00 Depth (MDrrVD) 5632 / .- 3131 Daily Cost 273310 Last C~g 9 5/8" @ 5615' MUD DATA DRILUNG DATA MUD TYPE DEPTH LSND ROT WT WEIGHT 9,6 ~ 22/26 e~.s 10/20 ^w ox ~ w~ 5.6 M~x Me H~P WL T~ ~M ~ ~n s~ &0 % T~ OF~ HOLE VOLUME 425 bU 25.0 ph LG$ 6.5 % DAILY MUD $ TOTAL MUD s247,36 BHA DESCRIPTION Est Accept I Days 5J) I Accpt 42. Previous Depth MD 5632 Cum Cost 699060 Next Csg 7" @ 11,445 -- Daily Drilling Reports I R ig Release - hr~ Progress 0 Est Cost To Date 550000 IShoe Te~t "' N/A BIT DATA EH&S 2 INCIDENT {Y N) N ~,~ EMPLOYER HYC SPILL(Y N) N DS70FGV 18793 6'11 VOLUME S~FEW~rG 12t2S/~ FUEL & WATER INJECTION FUEL USED INJECTION WELL 2M-23 SOURCE WELL 2F-18 RATE (~'n) 5 PRESSURE (p,a) g25 ~ESEL VOL (bi:~ MUD VOL 1350 WATER VOL (~ 0 TOTAL VOL(~ TOT FOR WE~ (~) DRILLS/BOP DATA LAST BOP/DIVERT TST I LASTBOP/DRILL LAS~H2~ DRILL LAST FIRE DRILL 11/23/96 [ 12/01/96 LAST CONFINED SPACE / LAST SPILL DRILL ~ ' 12/03/96 I 12/16/96 278O DRILL WATER USED-BBLS 18~0 POTABLE WATER USED-BBLS 130 WEATHER & PERSONNEL DATA TEMPERATURE, °F -8 WIND SPEED-KTS 0 CHILL FACTOR, °F -8 CONTRACTOR PERSONNEL 9R MISC PERSONNEL 17 TOTAL 45 BIT, MACH I XL (1.20°), NMS, NMSDC, XO, LWD, MWD, FS, NMS, 3 NMDC, XO, 4 HWDP, JARS, 25 HWDP BHA NO WIEGHT 00:00 00:30 lCD IpI~LLPIPI~ DATJ, (TOP TO BOTTOM) GR~. DE CONNECTION 1115.77 DATE LAST INSPECTED: HOURS ON JARS TIME OPERATIONS FROM 0000- (XX)0 FINISH RIH W/9 5/8" CSG. MU HANGER. LAND CSG AT 3615', 56L4" ICL.ASS 2 I LENGTH 00:30 02:00 CIRC 637 BBLS AT 9 BPM. NO LOSS. 02:00 04:30 04:30 06:00 06:00 08:00 08:00 11:00 TEST LINES TO 3500 PSI. DOWELL PUMPED 40 BBLS H20, 43 BBLS LEAD CEMENT AND 250 BBLS TAIL CEMENT. DISPLACED W/RIG PUMPS. LOST CIRC 346 BBLS INTO DISPLACEMENT. BUMPED PLUG. .g CHECK FLOATS. OPEN ES CEMENTER W/26'00 PSI. ClRC 400 BBLS MUD W/10~% RETURNS. HAD CONTAMINATED CEMENT AT BOTTOMS UP. PUMPED 20 BBLS H20, 216 BBLS LEAD AND 10 BBLS TAIL CEMENT. DISPLACED W/RIG PUMPS. HAD 90 BBLS 10.6 CEMENT TO SURFACE. CLOSED ES CEMENTER W/1200 PSI. PRESS TO 2000 PSI. CHECK CEMENTER. OK. LD LJ. WASH OUT CEMENT F/DIVERTER AND CELLAR (FLOW LINE PLUGGED W/CEMENT). MU SPEED HEAD. 11:00 13:30 13:30 18:00 18:00 24:00 NU BOPE. TEST ALL BOPE TO 300 - 5000 PSI. IBOP AND INSIDE KILL LINE VALVE FAILED. CHANGE OUT SAME. 24:00 qos¢ Supervisor Donald Lutrick ARCO Alaska, Inc. Cementing Details Well#: Casing Size 9 5/8" Centralizers 2F-18 Hole Diameter 12.25" Field: KUPARUK Hole Angle Shoe Depth 70° 5,615' Date: Float Depth 5,482' 12/25/96 % washout State type used, intervals covered and spacing 102 Gemco centralizers, l-4 = 2 per jt 5-27 (odd) 1 per jt 6-28 (even) 2 per jt 29-84 1 per jt 1 on each side of cementer Mud Spacer Lead Cement STAGE 1/2 Weight 9.8/9.7 Gels before I 5/26 Type Water YP(prior cond) 38 lbs/100 ft2 Gels after 8/15 Type I Mix wtr temp ASLW I 6 0 Additives YP(after cond) I PV(prior cond) 21 lbs/lO0 ft21 28 cP Total Volume Circulated 2 bbls Volume 40/20 No. of sacks 55/275 Weight 1 0.5/1 0.5 PV(after cond) 22 cP Weight 8.3 PPG Yield 4.41 Tall Cement STAGE 1/2 Displacement 'G + 3.5% DO44, .6% DO46, 30% D53, .1.5% DO79, 50% D124, 1.5% SOO1 Type IMixwatertempl Ne. of sacks Weight I Yield G/AS 1 60 1.15/0.93 Theoretical Displacement STAGE 1/2 416/1 16 Calculated top of cement CIP 11/26/96 2500'/surface 04:30 / 07:15 1220/60 I 15.8/15.8 STAGE 1: G, 2.66% DO29, .2% DO46, .3% DO65, 1% SOO1 STAGE 2: ASI Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 8 8 Reciprocation length Reciprocation speed Str. Wt. Dn. 15 10 fpm Actual Displacement Str. Wt. Mud 421/120 Bumped plug I FIoats held yes/yesI yes/yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. ~e 1: Reciprocated csg until cement rounded shoe. Became sticky. Circ 650 bbls mud w/no loss. Pumped lead and tail slurries. Displaced w/rig pumps. Had 100% returns until 346 bbls of displacement pump. Lost all returns. Had 223 bbls cement outside ~. est TOC at 2500'. Bumped plug e 2' Press csg to 2700 psi to open cementer. Circ 400 bbls mud w/ full returns. Had contaminated returns at bottoms up. 2nd stage lead and tail slurries w/ 100% returns through out entire job. Had cement to surface w/216 bbls lead pumped. Switched to tail slurry. Displaced w/ rig pumps. Closed cementer w/ 1200 psi. Cement Company I Rig Contractor Dowell I Parker Signature Donald Lutrick ARCO Alaska, Inc wo. 2 F- 1 8: Contractor' PAR KER Operation At 060~RI G MUDTYPE LSND 12/26/96 Rpt No 7 Rig Accept - hrs 12/21/96 17:00 Depth (MD/TVDg349 / 3415 245 Daily Cost 91341 -. Last Csg 9 5/8' @ 5615' MUD DATA DRILUNG DATA BIT DATA DEi~TH 6349 2 wEmm' 8.5 ~T wr wscoaw 45 --, ;PUWT 210 HYC 106 DS70FGV Ga.s 8/12 AVa ~,~, 10 ~ 12.5 MAX DeUU3 10 HTHP WL TRQ BTM ~OUD~ 2.0 % TRQ OFF 8000 Hm.E VOLUM~ ~U~P P~S 420 ~ 2200 5632 717 2.96/.87 10/12 75/MM Est Accept I Days 6 i Accpt 52 Previous Depth MD 5632 Cum Cost 790401 Next Csg 7" @ 11,445 Daily Drilling Reports Rig Release - hrs Progress Mm' 75 ph LGS 2.0 % PIT VOL DALLY MUD $ TOTAL MUD S36040 6'11 Est Cost To Date EH&S INCIDENT (Y N) N LAST BOP/DIVERT TST EM~o¥~ 12/26/96 S~,.L(Y N) N LAST~'~ DRILL 11/23/96 717 840000 Shoe Test "- 12.4 DRILLS I BOP DATA LAST BOP/DRILL LAST FIRE DRILL 12/01/96 LAST CONFINED SPACE LAST SPIM. DRILL VOLUME' :~ ' '1~ 12/16/96 sA~-rY~o 12/23/96 FUEL & WATER INJECTION FUEL USED INJECTION WELL 2M-23 DRILLWATER USED-BBLS soU.CE WELL 2F-18 2100 POTABLE WATER USED-BBLS 'F~TE (~) 120 PRESSURE (p~i) ~ WEATHER & PERSONNEL DATA DIESEL VOL ('ob~ 15 TEMPERATURE, °F -14 MUD VOL (b~) 2030 WIND SPEED-KTS 6 WATER VOL (bl~) CHILL FACTOR, °F -20 TOTAL VOL(I:~ 20~5 CONTRACTOR PERSONNEL ~0 TOT FOR WELL (bb~)79' MISC PERSONNEL 17 TOTAL 47 BHA DESCRIPTION BIT, MACH 1 XL (1.20°), NMS, NMSDC, XO, LWD, MWD, FS, NMS, 3 NMDC, XO, 4 HWDP, JARS, 25 HWDP BHA NO 2 OD WIEGHT BHA LENGTH 1115.77 DATE LAST INSPECTED:, HOURS ON JARS DAH0402 / 23.63 :00:00 01:00 FINISH CHANGE IBOP. DF~LLPIPE DATA ('TOP TO BO'I'rOM) GRADE 1 CONNECTION OPERATIONS FROM 0000 - , CLASS 2I LENGTH 01:00 02:30 TEST INSIDE KILL AND IBOP TO 300- 5000 PSI. RD TEST TOOLS AND SET WEAR BUSHING. 02:30 05'00 05:00 05:30 05:30 08:3~) 08:30 10:30 MU BHA. PROGRAM LWD. INSTALL SOURCE.. RIH. WASH OUT GREEN CEMENT TO 1485'. TEST CSG TO 2000', DRILL OUT ES CEMENTER, TEST CSG TO 2000 PSI. RIH , TAG GREEN CEMENT AT 5230'. PULL 2 STDS, 10:30 11:30 11:30 12:00 12:00 12:30 CBU. TEST CSG TO 2000 PSI F130 MINS. SERVICE TOP DRIVE. 12:30 16:30 16:30 17:30 17:30 18:30 18:30 24:00 24:00 DRILL CEMENT, LC, FC, FS AND 10' NEW HOLE TO 5642'. DISPLACE MUD W/H20. PERFORM LOT. FORMATION BROKE BACK W/8.4 MUD, 3134' TVD AND 660 PSI SURFACE PRESSURE = 12.44 PPG. DRLG F/5642' TO 6349'. ADT - 2.96 HRS. Supervisor Donald Lutrick CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 2F-18 Date: 12/26/96 Supervisor: Donald Lutrick Casing Size and Description' Casing Setting Depth: Mud Weight: 9 5/8", 40#, L-80, BTC 561 5 TMD 3125' TVD 8.6 ppg EMW= Leak-off Pressure (PLO) · + MW 0.052 x TVD LOT = 660 psi / (0.052 x 3134 ft) + 8.4 ppg = 12.45 ppg Fluid Pumped = 1.2 bbls. Hole Depth (md)= 10,246 Pump output = .101 bps 2100 20OO 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 gOO 800 700 60O 500 40O 300 200 100 0 J i - LEAK-OFF TEST ~--.B-- CASING TEST AFC NO AX9374 Date 2 F- 1-8 - Contractor PARKER Last Csg ARCO Alaska, Inc Rpt No I Rig Accept - hrs 1P/P7/96 ' 8, 12/21/96 17:00 Depth (MD/TVD;~660. / -- 5152 245 Daily Cost 90235 Operation At 0600 -. PREP TO SHORTTRIP @ 9251.' MUD DATA DRILUNG DATA MUD TYPE DEPTH LSND L:J660__ WE~>rr 9.0 VISOO&'TY 51 ROTWT 180K ,u wr 275K so~ 135K GELS 13/28 AVe D~a 20K AP~ 6.8 MAX ~,~ 20K HTHP WL T~ ~ ~ ~ 19K ~U~ 5.0 % T~ OFF 21K HOLE VOLUME 565 I:~ MBT ph 9.0 LGS 5.0 % PIT VOL DALLY MUD S 17131 TOTAL MUD $53171 BHA DESCRIPTION 9 5/8" @ 5615' BIT DATA 2 HYC DS70FGV 18793 16.62 / 7.01 10/12 75/MM 6'11 Est Accept ! Days 8.2[ Accpt 62 Previous Depth MD ~349 Cum Cost RR0636 . Next Csg 7" @ 11,445 EH&S INCIDENT Ct' N) N EMPLOYER SP,.L (Y N) N VOLUME SAFETY M'rG 12/27/'96 INJECTION INJECTION WELL 2M-23 SOURCE WELL 2F-18 RATE (bpm) 5,,5 PRESSURE Loel) ~X) ~ E SEL VOL (b~4) MUD VOL 1450 WATER VOL (bbl) 0 TOTAL VOL ('r~) 1506 TOT FOR WELL (b~4)9420 Dally Drilling Reports Rig Release - hrs Progress Est Cost To Date 2311 1,000,000 Shoe Te~t - 12.4 DRILLS I BOP DATA LAST BOP/DIVERT TST 12/26/96 . LAST~I2~ DRILL 11/23/96 LAST CONFINED SPACE · ; ' 12.J93FJ6 LAST BOP/DRILL 12J26/96 LAST FIRE DRILL 12/01/96 LAST SPill DRILL 12/16/96 FUEL & WATER FUELUSED 3219 DRILL WATER U~ED-BBLS 1400 POTABLE WATER USED-BBLS 120 WEATHER & PERSONNEL DATA TEMPERATURE. °F 12 WIND SPEED-KTS 14 CHILL FACTOR, °F -lO CONTRACTOR PERSONNEL 30 MISC PERSONNEL 16 TOTAL 46 BIT, MACH I XL (1.20°), NMS, NMSDC, XO, LWD, MWD, FS, NMS, 3 NMDC, XO, 4 HWDP, JARS, 25 HWDP BHA NO BHA LENGTH DATE LAST INSPECTED:. HOURS ON JARS 111.~77 DAH04021 OD WIEGHT DI~LLPIPE DATA ~ TOP TO BOTTOM) GRADE CONNECTION LENGTH 00:00 10:30 12:00 12:30 13:00 14:00 24:00 1 0:30 12:00 12:30 13:00 14:0~ 24:00 OPERATIONS FROM 0000 · 0000 DRLG F/6349'. TO 7754'. ADT - 6.94 HRS PUMP LO/HI VIS SWEEP. PUMP PILL. BLOW DOWN LINES. POH TO SHOE. NO PROBLEMS. SERVICE TOP DRIVE. RIH TOTD. NO PROBLEMS. DRLG F/7754' TO 8660'. ADT - 6.63 HRS (PUMP LO/HI SWEEPS AT 7754' AND 8320') Supervisor Donald Lutrick ARCO Alaska, Inc Daily Drilling Reports AFC NO I Date Rpt No I Rig Accept-hrs Est Accept IDays Rig Release-hrs AX9374 12/28/96 9 12/21/96 17:00 92 Accpt 72 Well 2 F- 1 8 DePth (MD/TVD)6608 Previous Depth MD Progres~ / 5158 6349 2311 Contractor PARKER 245 DailyCost Cum Cost Est Cost To Date 113512 994148 1,000,000 Operation At 0600 Last Csg Next Csg Shoe Test PREP TO SHORT TRIP @ 9251' 95/8" @ 5615' 7" @ 11,445 12.4 MUD DATA DRILLING DATA BIT DATA j EH&S DRILLS! BOP DATA MUD TYPE LSN D DEPTH ~ BIT,O 2~ INCIDENT Or N) N LAST BOP/DIVERT TST LAST BOP/DRILL ROT w'r ~ EMPLOYER 12/26/96 12/26/96 WEIGHT 9.0 pm 180K J ~5 LAST H2S DRILL LAST FIRE DRILL wscosiTY 51 ~.~ Pu wT 275K M~ , HYC SP~LL~ N) N 12/23/96 12/07/96 PV/~ 15/27 so~ 135K ~ DS70FGV LAST CONFINED SPACE LAST SPILL DRILL VOLUME 1~ 12/16/96 -GELS 13/28 ^VG DRAG 20K SERIAL NO 1~793 DEPTH OUT SAFETYMTG 12/27/96 FUEL & WATER APl WL 6.S MAX ~G 20K HTHP WL TRQ BTM DEPTH IN INJECTION FUEL USED mi/30 min 19K 5632 , 3219 INJECTION WELL 2M-23 DRILLWATER USED-BBLS SCUDS S.O % TRQ OFF 21K FOOTAGE 302~ 1400 hOLE VOLUME PUMP PRES ADT/AST SOURCE WELL 2F-18 565 bU 2900 16.62/7.01 POTABLE WATER USED-BBLS RATE (b~) 5.5 120 PUMP 1 3 WOB 2 M~T 125 R~ .o 1(Y12 PRESSURE(psi) 900 WEATHER & PERSONNEL DATA ph 9.0 INFR .q2 6 6 RPM 1 75~/~ M DiESELVOL (bi:fl) LGS JETSTFA ~ TEMPERATURE, °F 12 S,0 % SPM 1 78 78 6'11 MUD VOL (bbt) 1450 WIND SPEED-KTS 14 PIT VOL 475 b/D{GPM 2 331 331 BIT COST ~),0~3 WATER VOL (bbl) 0 CHI LL FACTOR, °F '10 TOTAL MUD $70302 SPPI 27~ 375 GRADE TOT FOR WELL (bI~) 10926 MISC PERSONNEL 16 MUD w-r 9,0 9.0 TOTAL 4~ BHA DESCRIPTION BIT, MACH 1 XL (1.20°), NMS, NMSDC, XO, LWD, MWD, FS, NMS, 3 NMDC, XO, 4 HWDP, JARS, 25 HWDP BHA NO D~LLPIPE DATA {TOP TO BOTTOM) 2 OD WlEGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 1115.77 DATE LAST INSPECTED: HOURS ON JARS DAH0402 / T~VE 00:00 10:30 12:00 12:30 13:00 14:00 24:00 10:30 12:00 12:30 13:00 14:00 24:00 OPERATIONS FROM 0O00. 0000 DRLG F/6349' TO 7754'. ADT - 6.94 HRS PUMP LO/HI ViS SWEEP. PUMP PILL. BLOW DOWN LINES. POH TO SHOE. NO PROBLEMS. SERVICE TOP DRIVE. RIH TO TD. NO PROBLEMS. DRLG F/7754' TO 8660'. ADT - 6.63 HRS (PUMP LO/HI SWEEPS AT 7754' AND 8320') Supervisor Donald Lutrick ARCO Alaska, Inc Daily Drilling Reports AX9374 12/29/96 10 12~21/96 17:00 9.2 Accpt 82 Well 2 F. 1 8 Depth (MDrFVD)5919 Previous Depth MD Progress / 6079 9343 248 Contractor PAR KER 245 Daily Cost Cum Cost Est Cost To Date 149852 1144000 1,000,000 Operation At 0600 Last Csg Next Csg Shoe Test LD EIHA 9 5/8" @ 5615' 7"@ 11,445 12.4 MUD DATA DRILLING DATA BIT DATA EH&S DRILLS / BOP DATA MUD TYPE LSN D DEPTH 9591 BIT NO 2 INCIDENT Cr N) N LAST BOP/DIVERT TST LAST BOP/DRILL ROT WT SIZE EMPLOYER 12/26/96 12/28/96 WEIGHT 11.5 pm 200K 8.5 LAST H2S DRILL LAST FIRE DRILL wscosrn' 46 sec i PU WT 285K ~ HYC SPILL(Y N) N 12/23/96 12./07/96 ~v/~P 46/19 sowr TYPE TW'E 165K DS70FGV LAST CONFINED SPACE LAST SPILL DRILL VOLUME 1~ 12/16/96 ~ELS 5/6 AVS D~ 20K SER~L,O 18793 AP~ 4.6 M~X ORA~ 20K DEPTN OUT S~F~W~ 12/27/96 FUEL & WATER NTHI~ WL TRQ m'M DEPTH ~N INJECTION FUEL USED mV3O r~n 15K 5632 2184 INJECTION WELL 2M-23 DRILL WATER USED-BBLS soups 14.0 % TRQ OFF ~17K FOOTAGE 39~9 HOLE VOLUME PUMP PRES AD'I'/AST SOURCE WELL 2F-18 1200 628 bl~ 2500 23,37/9.31 POTABLE WATER USED-BBLS R~TE (~) 5.5 120 PUMP 1 3 WOB 2 M~T 15.0 I~ .O 10/12 PRESSURE(psi) ~ WEATHER & PERSONNEL DATA ph 8.0 I INFR S~ 6 6 RPM ~ 75/MM D~ESELVOL (bbl) LGS JETS TFA 45 TEMPERATURE, °F -18 42 % SPM ~ 6'11 MUD VOL (bbl) PITVOL GPM2 !BrrcosT 2~0 WIND SPEED-KTS 350 bbl ~0~0~3 WATER VOL (b~) 0CHILL FACTOR, °F -18 TOTAL MUD $147444 s~ 1 GRADE TOT FOR WELL (biN) 11231 MISC PERSONNEL 17 MUDWT 115, TOTAL 47 BHA DESCRIPTION BIT, MACH I XL (1.20°), NMS, NMSDC, XO, LWD, MWD, FS, NMS, 3 NMDC, XO, 4 HWDP, JARS, 25 HWDP BHA NO DFULLPIPE DATA (TOP TO BOTTOM) 2 OD WIEGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 1115.77 DATE LAST INSPECTED: HOURS ON JARS DAH0402 / TIME OPERATIONS FROM 0000 - 0000 00:00 00:30 01:30 02:00 05:30 14:30 15:30 18:00 21:30 23:00 24:00 00:30 01:30 02:00 05:30 14:30 15:30 18:00 21:30 23:00 24:00 DRLG F/9343' TO 9448'. ADT - .71 HRS HAD 5' DRLG BREAK F/9443' TO 9448'. CBU. NO GAS. DRLG F/9448' TO 9505'. ADT - .59 HRS. TOP OF C SAND AT 9497'. CBU. GAS CUT MUD TO SURFACE. 4000 UNITS GAS. INCREASE MUD WT TO 10.8. MONITOR WELL. CBU. 1600 UNITS GAS. WELL 1/2 BPM MUD TO FORMATION. MIX 15 PPB BAROFIBER. INCREASE MUD WT TO 11.1 PPG. MONITOR WELL FOR FLOW BACK 15 MIN. CBU. MAX GAS 1000 UNITS. DRLG F/9505' TO 9591'. ADT 1.0 HR MUD LOSS 1.5 BPM. REDUCE PUMP RATE TO 400 GAL MIN TO BUILD VOLUME. HAD CONTINUOUS OIL AND GAS CUT MUD AT BOTTOMS UP. ADD LCM F/20 PPB CONCENTRATION. INCREASE MUD WT TO 11.3. CONTINUOUS OIL AND GAS CUT MUD. INCREASE MUD W-I- TO 11.4 PPG. REDUCE PUMP RATE TO 273 GPM. INCREASE LCM TO 24 PPB. LOSS - 1 BPM INCREASE MUD WT TO 11.5 PPG. REDUCE PUMP RATE TO 160 GPM. LOST 95% RETURNS W/11.5 AT BIT. MIX AND SPOT 100 BBLS 12 PPG MUD. PREP TO POH. Supervisor Donald Lutrick l' ,f' ARCO Alaska. Inc iAFONO ' ' tDate Rpt.o IRigAocept-hrs AX9374 I 1;)/30/96 11 12/21/96 17:00 w°' 2 F- 1 8: Depth (MD/TVDJ59 - 1 / .. 6079 c°ntract°r~ PARKER 245 DailyCost 101'438 , Operation At 0600 " -i Last Csg MIX LCM ANI ) ClRC LCM 9 5/8' @ 5615 Est Accept ~ Day. ' 9.2J Accpt 92. Previous Depth MD Cum Cost 1245438 Next Csg 7" @ 11,445 Daily Drilling Reports Rig Release - hm Progress_ 0 Est Cost To Date 1 ..Sh°e Test 12.4 DRILLS / BOP DATA LAST BOP/DIVERT TST LAST BOP/DRILL 12/26/96 12/28/96 MUD DATA DRILUNG DATA MUD TYPE DEPTH LSND ~ WE~(~r 11.5 r~ ~OT w'r HTHP WL AVG DRAG MAX DRAG souo~ 12.9 % TI=K3 OFF HOLE VOLUME I~JMP PRES 628 I~ MaT 15.0 ph LGS 2.0 % Pff VOL DAILY MUD $ 29669 TOTAL MUD s177403 BHA DESCRIPTION. BIT DATA 2 HYC DS70FGV 5632 3959 23.3719~31 10/12 75/MM 6'11 EH&S INCIDENT (Y N) N EMPLOYER a,,u. (Y N) N TYP~ ' VOLUME' INJECTION ~cT.O. WE~ ~ ~,~a' sOU.CE W~U. 2F-181 RATE (bi-n) 5~ I~ESSURE (1:~1) ~ I~ESEL VOL (bb0 ~ MUD VOL (b~ WATER VOL (bbl) 0 TOTAL VOL (bbl) 6'J8 TOT FOR WELL (bbl) 1184CJ '~AST H2S DRILL ~ "l ~'2wgs LASTCONFINEDSPACE ~' ,12/o396 LAST FIRE DRILL 12/07/96 LAST SPILL DRILL 12/16/96 FUEL & WATER FUEL USED 3180 DRILL WATER U~ED-BBL8 POTABLE WATER USED-BBLS 120 WEATHER & PERSONNEL DATA TEMPERATURE, °F -18 WIND SPEED-KTS CHILL FACTOR, °F -18 CONTRACTOR PERSONNEL 2~ MISC PERSONNEL 18 TOTAL 47 BIT, NBS, NMSDC, NMS, NMDC,NMS, 2 NMDC, 3 DC, XO, 4 HWDP, JARS, 25 HWDP BHA NO 3 OD WIEGHT BHA LENGTH 1110.6 D~LLPIPE DA1 GRADE DATE LAST INSPECTED:, HOURS ON JARS DAH0402 I TIME OPERATIONS FROM 0000 · ~OPTOBOTTOM) CONNECTION I CI.ASS 2 I LENGTH 00:00 00:30 00:30 07:30 07:30 13:00 13:00 14:00 14:00 16:0~0 16:00 19:00 19:00 24:00 24:00 SPOT 100 BBLS 12 PPG MUD. POH. LD BHA. RIH TO SHOE SLOW. PUSH AWAY MUD TO FORMATION LAST 5 STDS. SLIP AND CUT DRLG LINE. RIH TO 8036'. CIRC 100 BBLS AT 4 BPM W/50% RETURNS. LARGE AMOUNT OF GAS AND OIL IN RETURNS. RIH TO 8500'. RIH TO 8500'. CIRC AT 3 BPM W/25% RETURNS. RIH TO TD. MIX AND ClRC 45 PPB BAROSEAL FINE. MEDIUM, FINE QUICK SEAL, MED QUICK SEAL, MEDIUM AND CORSE WALL NUT. ClRC AT 2.5 BPM W/0 TO 75% RETURNS. Supervisor Donald Lutrick PflRKER-245 I?"907-659-?106 3fin 08'9? 6'05 No,O05 P,O1 BAROID DRLG.FLUIDS DRILLING MUD REPORT [quMB~R- O--FER TOR ARCO ALASKA INC. REPORT FOR GUY WHITLOCK WELL N-------AME AND NUMBER GOLD HILL BIT DATA T OD Je~ ] Lar OD Tot Noz ~ea TFA MUD PROPERTIES FL DeRth ft FV~O '- lbs F ,, ..... Gels lbs APl { vol vol . {Date ..... { DePth .... - -- -' R~G NUM"~R PARKER DRLG I__NC. ._. ~ m,.,~u~ ~NG . I _ ; - .,- DRILLING STRING OD ~ ID 4,276 ~n, OD ID Len. OPEN BOLE 8.5 Len. 706 ze Len, 22 16 2 3 CA~ING' ~IRCULATION DATA 4.0 5614 E~SCO 6X12 0.0 6 X 12 Eft, 0 m 0,0 169 4.0 80 263 MUD TREATMENTS 680 bbls FOR $34,847,00. o, 101 Sand % 13 vol M]~C 5,0 STRIP ?.5 0.~0 Al&. Mu~ , RIG ACTIVITY FU~P CBT PLU~, TOH 1~ $TDS PUMP SLUG, DH 13 STDS, &HUT IN WEL~, PU~P ~ ~U~, ~, HOLE STATIC, TX~ TAG ~ ~ 5934, ~H WELL F~S 12 BPH, T~ ~P, WELL F~$ 28 BPH, TIH ~ SHOE, ~NI~R ~L~, ~W ~T K{LLY Hard, C~ Low 31.58 USED ~ NA~ s os ALDACIDB - 55 (?A{~, DRUM 1 1577.S9 BAI~ASAN-D ' 25 ~, ~G 1 16~.~2 ~g~in9- 1 ~, 2 10~.~ ba~i%e 1~ ~. BA~ 56 · B6~,76 l~iJD VOLUME --bbl{ MUD TYPE [ Hole ..... { Pits -{ LSND 600 rpm 433 {,. _625 { .... MUD CONSUltaTION 300 ...... ActiveVolhme ' , {?rp, · i058 { 1 -- Reservd .... ii'oral · 600 1658 ppb 31.58 Hlgh'Or~V, vol % 10.5 ppb 154.35 Af~] 3.84 ADDITIONS Oil {~ine Water. Drill water ~a Water Whole Mud Barite Chemicals 3 rpm Pressure Units; P~s~s Drop, DP 124 P~e~s Drop, BIT 0 A~ Circ. LOSSES bbl ~111 Cuttings 0 Immp~d 0 AV, DP ft/min 78 I Angle Dilution Rate 0.00 l~st 0 AV, ~ ft/m.in 0 ! Direction 51ds Control l~ff 0.00 VOL OAIN/t_O_~_q 270 ,~V_Rise~ ft/mln [ Horizo Dlsp.! BAROI'D' ~ENTATIVE .... _ _ [ O-F'~iCE/HOME 'lN~O~d{~-- [TBbEFi{~E .... 248;3511 3, i}[L~ON & C. Al)ELS ............ [WARBi{OUSI~ ........... PI~'OD~E BA~ ..... [TELBPHOiqB 659-2422 ¢~10, F, Orad 0,0 I~ak Off Test 0,0 ECD PP9 C~9, $~ 12,0 TD 12,0 {lax. Diff. ~e~ 0 VlAT~O'N ZNFO -- -Szo rt 64,~ ClRC TRIPS SERV, RIG SUR~ FISHING ~INO RUN USO CORE BACK REAl{ REAMING TESTING 172.92 4710 £t AVENGE ~-~-0 0,00 9.00 0.00 0,00 0.00 0,00 0,00 0.00 0,00 0.00 0.00 15,00 0.00 ~ . 3662,12] $ )14~62,57 ~e recommendations mad~ hereon shall not b~ construed as authorilin9 the infrlngement of any valid,p,atent, and are ma~ without assumption of any liability by BAROID DRILLING FLUIDS~ INC. or its agents, and a~e st~at_e{ents of opinion only. JAN 0 8 ]997 AJaska O~ & Gas Cons. ~rnmission ~chorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well _ Change approved program _ Operation Shutdown Re-enter suspended well Plugging __ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, IBC. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1244' FNL, 778' FEL, Sec 4, T10N, R9E, UM At effective depth At total depth 1244' FNL, 778' FEL, Sec. 4, T10N, RgE, UM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) RKB 41', Pad 97' 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-18 Gold Hills 9. Permit number 96-178 10. APl number 50-029-22720 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 12. Present well condition summary Total Depth' measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 5787' 11 471 ' 2208' measured None 13720' 9908' Size 16" 9-5/8" . feet Plugs (measured) feet feet Junk (measured) feet None Cemented 200 sx CF 1030 sx ASIII 1100 sx Class G 370 sx Class G 290 sx Class G ORISINAL Measured depth True vertical depth 121' 121' 5828' 3138' 11512' 7700' 13720' 99080 true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal __ Detailed operation program BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Suspended Service 17. I herelbY,_l certify, thati .... the,, ~J~f°reg°ing is true and correct tO~r..the best of my knowledge. Signed ~ .... ,. o i r-~.~"__~-.~\.. Title A-fe~ Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Sigrie,.: .. David W. duhll,~t01~. IAPRroval Commissioner SUBMIT IN TRIPLICATE Approved Corn.. //~.~ ,'~ Returrleci .. ..... . 'I'QNY KNOWL£$, GOVERNOR November 25, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 FHONE: (907) 279-1433 FAX: (907) 276-7542 Michael Zanghi ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-036 Re: Kuparuk River Unit 2F-18 ARCO Alaska, Inc. Permit No: 96-178 Sur. Loc. 128'FNL, 1738'FEL. Sec. 33, TI IN. R9E. LrM Btmholc Loc. 1244'FNL. 778'FEL. Scc. 4. TI0N. RgE. UM Dear Mr. Zanghi: Enclosed is thc approved application for permit to drill thc above rcf'crcnccd xx'cll. Thc pcrmit to drill docs not cxcmpt you from obtaining additional permits required by law from other govcrruncntal agcncics, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. A weekly status report is required from thc time thc well is spuddcd until it is suspended or plugged and abandoncd. Thc report should be a generalized ssanopsis of thc wcck's activities and is exclusively for thc Commission's int,m~al usc. Approval for annular injection is contingent on thc operator's submittal of an Application for Sundry Approvals (10-403) with pcrtincnt facts and evaluation of surface hole conditions, casing placcmcnt, cementing, and any diagnostic logs that werc run. The documcntation submitted should include a CQL or a valid LOT to assure thc Commission that an adcquatc seal has been attained and that the well has bccn cased and cemented according to regulation. Blowout prevention equipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE test pcrformcd before drilling below the surface casing shoe must be given so flint a representative of thc Commission ma.,,' witness the test. Notice may be given bv contacting the Commission pctrolcum field inspector on the North Slope pager at 659-3607. Chairman~ BY ORDER OF THE COMMISSION dlPEnclosures Deparlmcnt ol'Fish & Game. l labitat Section w,'o cncl. I)cparlmcnt of l';nvimnmcntal ConscrYaliun w;o cncl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 James R. Winegarner Senior Landman Land Department ATO 1496 Phone (907) 265-6914 Fax (907) 263-4966 November 8, 1996 KUPARUK RIVER UNIT WORKING INTEREST OWNERS REPRESENTATIVES AND ALTERNATES Re- KRU Ballot No. 251 BALLOT AND AGREEMENT FOR ALLOWING USE OF KPA UNIT EQUIPMENT FOR TEST WELL (2F-18) ARCO Alaska, Inc. and BP Exploration (Alaska) Inc., as Tract Owners of KRU Tract 78, wish to drill an exploratory test well ("2F-18") from KPA Drillsite 2F into KRU Tract 78. The enclosed KPA Ballot No. 251 will allow the Tract Owners to drill 2F-18 and use KPA Unit Equipment. After your review, please execute the enclosed Ballot by signing in the space provided for your company. Please fax a copy of your executed signature page to me at (907) 263-4966 before returning the original to my attention at the letterhead address. Sinc~ , ,/'Senior Land~'~l~mes R' Wi~r, CPL Enclosure / If you have any questions, please call me at (907) 265-6914. RECEIVED NOV .2 '1 1,996 Alaska 011 & fl~s C_nns {;r,~mmlssion Anchorag0 KPA BALLOT No, 2~ BALLOT AND A~REEMENT FOR ALLOWI~ I~1~11~~ UNIT EQUIPMENT FOR TEST WELL (Drillsite 2F) THIS BALLOT AND AGREEMENT is made and entered into by and between the Kuparuk Participating Area ("KPA") Working Interest Owners ("WIOs") and the undersigned WIOs in their capacities as Tract Owners of Tract 78 (ADL-25666) within the Kuparuk River Unit ("Tract Owners"). WHEREAS, the Tract Owners wish to drill an exploratory well from KPA Drillsite 2F into Tract 78 ("Test Well") and the parties may wish to conduct testing and production operations to determine if the well is capable of sustained commercial production of Unitized Substances in sufficient quantities to justify developing and producing the objective hodzon; WHEREAS, Tract Owners wish to use a KPA well slot and interconnection with the KPA production facility defined herein below in order to conduct Tract Operations from Tract 78. WHEREAS, the KPA WlOs, own and operate Unit Equipment which have capacities sufficient to accept production from Tract Operations being conducted from Tract 78. WHEREAS, the KPA WIOs, in accordance with Subsection 14.001.02 and Section 16.005 of the Kuparuk River Unit Operating Agreement ("KRUOA") and pursuant to the terms and conditions as described in this Agreement and Ballot, desire to share KPA Unit Equipment with the Tract Owners of Tract 78, who have executed this Ballot and Agreement, in the spaces provided below, for use in connection with Tract Operations being conducted on Tract 78. NOW, THEREFORE, in consideration of the covenants and mutual promises contained herein, the Parties agree as follows: Tract Owners of Tract 78 shall be allowed to conduct Tract Operations for the Test Well from KPA Drillsite 2F, including the use of a ddlling slot and the interconnection with KPA production facilities located on KPA Ddllsite 2F. . Production fluids from the Test Well may be commingled with KPA production provided that the production fluids are measured pdor to commingling. The total amount of oil dedved from the production fluids from the Test Well shall not exceed 75,000 barrels. Production fluids from the Test Well, limited to 75,000 barrels of oil, shall be granted to the KPA owners at the 2F production site. The KPA owners shall reimburse the tract owners for the royalties and production taxes attributable to all production fluids from the Test Well. . The Tract Owners shall defend, indemnify and hold harmless the KPA WlOs from and against any claims or damages to Unit Equipment or injury to personnel that may result from such Tract Operations. Further, the Tract Owners shall assume full responsibility for and shall defend, indemnify and hold the KPA WIOs harmless from and against any loss, damage, expense, claim, fine and penalty, demand or liability for pollution or ,allot and Agreement Allowing Use of KPA Unit Equipment for Test Well (Drillsite 2F) Page 2 KPA Ballot No. 251 contamination, including control and removal thereof, from spills, leaks or discharges of muds, engine oil, hydraulic fluids, chemicals, etc. resulting from the Tract Operations, including but not limited to, the hauling of or disposal of muds and cuttings. Tract Owners shall clean up such spills, leaks or discharges immediately upon discovery. Tract Owners shall .fully comply with all applicable federal, state, local, and contractual requirements pertaining to control and removal of spills, leaks and discharges. Tract Owners shall maintain sufficient procedures and have access to sufficient equipment to control and remove any such spills, leaks or discharges. Initiation of cleanup activities by either party shall not be an admission or assumption of liability by such initiating party. . This Ballot is effective when approved by the Tract Owners and by 88% vote of the KPA WlO's. o The term to utilize the KPA Unit Equipment by Tract Owners of Tract 78 shall be restricted to a term of one year, measured from October 1, 1996. . All capitalized terms found in this Ballot and Agreement shall have the same meaning as defined in the KRUOA. . In the event of a conflict between the terms and conditions of this Ballot and Agreement and the terms and conditions of the KRUOA, the terms and conditions of the KRUOA shall prevail. This Ballot and Agreement may be executed in one or more counterparts each having the same effect as if all parties had executed the same instrument. IN WITNESS WHEREOF, the Parties have executed this Ballot on the day opposite their respective signatures. TRACT OWNERS- TRACT 78 ARCO ALASKA, INC. Title: Date: BP EXPLORATION (ALASKA) INC. By: Title: Date:, .~allot and Agreement Allowing Use of KPA Unit Equipment for Test Well (Drillsite 2F) Page 3 KPA Ballot No. 251 KUPARUK PARTICIPATING AREA WORKING INTEREST OWNERS ARCO ALA A, Title: Date: ,o//&~( [ct(c, BP EXPLORATION (ALASKA) INC. By: Title: Date: CHEVRON U.S.A. INC. By: Title: Date: EXXON By: Title: CORPORATION Date: MOBIL OIL CORPORATION By: Title: Date: UNION OIL COMPANY OF CALIFORNIA By: Date: Title: KUPARUK RIVER UNIT WORKING INTEREST OWNERS S. I. Kerr (Scott) ARCO Alaska, Inc. 700 "G" Street / ATO-1220 P. O. Box 100360 Anchorage, AK 99510-0360 Fax: (907) 265-6133 A. M. Garon (Allan) BP Exploration (Alaska), Inc. 900 E. Benson Boulevard P. O. Box 196612 (MB7-3) Anchorage, AK 99519-6612 Fax (907) 564-4680 J. A. Ricotta (Jim) Chevron U.S.A., Inc. P. O. Box 1635 Houston, TX 77251 Fax: (713) 754-5626 R. G. Dragrdch (Rob) Exxon Company, U.S.A. 3301 "C" Street / 4th Floor P. O. Box 196601 Anchorage, AK 99519-6601 Fax: (907) 564-3789 G. M. Moffitt (Mike) Mobil Oil Corporation 12450 Greenspoint Drive Houston, TX 77060-1991 Fax: (713) 775-4118 C. A. Costelloe (Christopher) Union Oil Company of California 909 West 9th Avenue P. O. Box 196247 Anchorage, AK 99519-6247 Fax: (907) 263-7828 CC: Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Fax: (907) 276-7542 Mr. Kenneth A. Boyd, Director Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Fax: (907) 562-3852 RECEIVED NOV Alaska Oil & (3as Con~. Commission Anehorago ~RCO Alaska, Inc. Legal Departme,,, Post Office Box 100360 Anchorage Alaska 99510 Telephone 907 265 1354 Facsimile 907 265 6998 Daniel G. Rodgers Counsel November 15, 1996 RECEIVED NOV 1 9 1996 Mr. Bob Crandall Alaska 0il & Gas Cons. Commission Alaska Oil and Gas Conservation Commission Anchorage 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Crandall' In accordance with 20 AAC 25.005 and 20 AAC 25.050 (b), ARCO Alaska, Inc. has filed an application for a Permit to Drill (Form 10-401) for the 2F-18 Well. The drilling location set forth in the application is on land subject to the Kuparuk River Unit and is 660 feet or more from the exterior boundary of the Kuparuk River Unit. Jim Winegarner indicated that you requested a letter from me regarding the provisions of the Kuparuk River Unit Agreement and the Kuparuk River Unit Operating Agreement relating to the drilling of the 2F-18 Well. The Kuparuk River Unit and the Kuparuk River Unit Agreement were approved by the State'of Alaska o'n March 26, 1982, effective December 1, 1981. The Kuparuk River Unit Agreement has also been approved and executed by all of the Working Interest Owners of the Kuparuk River Unit. Article 3.1 of the Kuparuk River Unit Agreement provides as follows: 3.1 Oil and Gas Rights Unitized. All Oil and Gas Rights in each of the Tracts [leases] described in Exhibit A are unitized so that Unit Operations may be conducted as if the Unit Area had been included in a single lease executed by the State of Alaska and any other party who may have authority to execute oil and gas leases, as lessor, in favor of all Working Interest Owners, as lessees. ADL-25657 and ADL-25666 are leases listed on Exhibit A and subject to the Kuparuk River Unit Agreement. The Kuparuk River Unit Agreement defines Unit Operations as "all operations conducted under this Agreement and the Unit Operating Agreement." The 2F-18 Well will be drilled by ARCO Alaska, Inc. on behalf of ARCO Alaska, Inc. and BP Exploration (Alaska), Inc., the Working Interest Owners of ADL-25657 and ADL-25666. This drilling activity will be conducted as a Unit Operation in accordance with the Kuparuk River Unit Agreement and the Kuparuk River Unit Operating Agreement. The Kuparuk River Unit Operating Agreement, which has ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Mr. Bob Crandall November 15, 1996 Page 2 been approved by all the Working Interest Owners of the Kuparuk River Unit, defines Tract Operations as Unit Operations. The drilling of the 2F-18 Well will be conducted in accordance with the Tract Operations provisions (Article 16) of the Kuparuk River Unit Operating Agreement. In short, the 2F-18 well will be drilled as a Unit Operation pursuant to the Kuparuk River Unit Agreement and the Kuparuk River Unit Operating Agreement on land entirely within the boundary of the Kuparuk River Unit. It will be drilled 660 or more feet from the boundary of the Kuparuk River Unit. 20 AAC 25.050 (c) provides that the items listed in 20 AAC 25.050 (b)(2) and (3) are not applicable to a well drilled on land subject to an approved unit and located 660 feet or more from the exterior boundary of the unit. Consequently, there are no "affected owners" for the purposes of 20 AAC 25.050, and the commission should promptly approve the Permit to Drill which has been submitted under 20 AAC 25.050 (b). Please call me at 265-1354 if you have questions about the foregoing. Very truly yours, Daniel G. Rodgers ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1 215 October 28, 1996 Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Re: Dear Sirs: Application for Permit to Drill ARCO 2F-18, Gold Hills ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory tail below KRU 2F- 18. The well is designed to penetrate the Sag River, Ivishak and Lisburne formations. Upol~ completion of either drilling or testing the exploratory tail, the well will be reverted back to a Kuparuk well. Attached find the information required by 20 ACC 25.005 (c) for your review. Other pertinent information attached to this application is confidential data including the following: 1) Pressure information as required by 20 ACC 25.035 (d) (2). 2) Prediction of overpressured strata as required by 20 ACC 25.033 (e). 3) Annulus pumping request as required by 20 ACC 25.005 (c) (10). There are no shallow hazards expected at 2F-18, such as shallow gas. There have been 16 wells drilled on KRU 2F pad and shallow gas has not been encountered. Therefore, ARCO requests a waiver from 20 ACC 25.005 (c) (8). Please note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment operating as is the usual case while drilling wells in the Kuparuk field. If you have any questions or require any further information, please contact me at 265-6434 or Mike Zanghi (ARCO Kuparuk Drill Site Development Supervisor) at 265-6206. Sincerely, James Trantham Project Manager (SDE) Attachments cc: 2F-18 Gold Hills Well File Steve Porter ATO-1396 John Braden ATO-1460 ARCO Alaska Inc. is a subsidiary of Allantic Richfield Company ALA$~,~ OIL AND C.¢,$ CONSERVATION COMMISSI~,~ PER~IT TO ORILI 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory X Stratigraphic Test F~ Development Oil X Re-Entry [--] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 97' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25666, ALK 2587 Lisburne ExpI. Tail 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 128' FNL, 1738' FEL, Sec. 33, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1244' FNL, 778' FEL, Sec. 4, T10N, R9E, UM 2F-18 #U-630610 Gold Hills At total depth 9. Approximate spud date Amount 1244' FNL, 778' FEL, Sec. 4, T10N, R9E, UM 1 2/1/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD ~nd TVD) property line 13720' MD 778 ~ TD feet 14.4' to 2F-15 feet 2560 9908' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(d)(2)) Kickoff depth 300' feet Maximum hole angle 73 o Maximum surface 3560 psig At total depth (TVD) 4800 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 12.25" 9.625" 40.0# L-80 BTC 5786' 41' 41' 5828' 3138' 1030 Sx Arcticset III & HF-ERW 1110 Sx Class G 8.5" 7" 26.0# L-80 BTCMOB 11470 41' 41' 11512' 7700' 370ClassG 6.125" 5" 18.0# L-80 LTC 2208' 11512' 7700' 13720' 9908' 290 Sx ClassG HF-ERW Top 500' above Kuparuk 19. 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 RECEIVED Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Al~sk.-']'. 0ii & O?,S (i_:O'~S. C%lrn~SSi0ll Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certifytha thefor~oi,g/// is true and correctto the best of my knowledge Signed ~/k."~/r.~_~...;~. ~, Title Drill Site Develop. Supv. Datel~ k-J'/API r~ r--/ ~mber Commission Use Only Permit Number _ I Approval date -, _ ~. ,,~- I See cover letl'er for ~'"~' ,.,//,7 ¢ J ~¢"- 0 ~ "~ '"' ~ "'~ ~ "~'"4~' J / 1 ~' ¢2~,.~, ~¢bJ other requirements Conditions of approval Samples required [] Yes [] No Mud logrequired '~ Yes [] No Hydrogen sulfidemeasures [] Yes J--'J No Directional survey required ,~ Yes FJ No Required working pressure for BOPE [] 2M [] 3M J~J 5M [] 10M [] 15M Other: Original SigneO Cy by order of // Approved by David W. Johnstor, Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 2F-18 Gold Hills Exploration Tail I . . . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5828')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test(16 ppg EMW max). Drill 8-1/2" hole through the Kuparuk to above the Sag River formation @ 11700' according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (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 7" casing to 3500 psi. Drill out cement and 10' of new hole. Perform leak off test(16 ppg EMW max). Drill 6-1/8" hole through the Sag River and Ivishak formations. Run open hole evaluation logs or LWD tools as needed prior to penetrating the Lisburne formation. Continue drilling through the Lisburne formation to TD @ approximately 13720'. Run open hole evaluation logs or LWD tools as needed. If the well is to be tested, run 5", 18#, L-80 casing liner. (If the well will not be tested, prepare the well for Kuparuk production by completing the well (steps 19-23 with Parker #245)). Run 3-1/2", 12.9# tubing for a test string. BOPE. NU tubinghead. Prepare the well for testing with CTU. Sting into the top of the liner. ND ECEIVED Shut in and secure well. RDMO Parker #245. Prepare location for extended flow test through 2F facilities. AI,-,o~(., 0i~ .~'. ¢,-,,.. 0:,,-,,-~ t.;'.):lifillSSiO[-I ~(t,_J, I.: ~ ~.. '' :. ,-.. ,D. Test zones as appropriate. When complete, plug and abandon as per AOGCC a~'"'-"~"'*m'.,::,:,_: ~.~,, regulations. RD CTU and test facilties when complete. MIRU Nordic 2. ND tubinghead. NU BOPE. Pull test string and ensure lower section is abandoned appropriately. 19. Run completion assembly. Set packer and pressure test tubing and annulus. 20. ND BOPE. NU tubinghead & either full opening valve (if injector and logging planned) or master valve and upper tree assembly (if producer and no logging planned). Note: If the well will be a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. 21. Install production tree. 22. Shut in and secure well. 23. Clean location and release rig in preparation for perforating. RILLING FLUID PROGRAM Well KRU 2F-18 Gold Hills Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 20-26 15-25 50-70 5-15 15-40 10-12 9.5-10 +10% Intermediate casing 10.5 16-20 15-20 30-40 4-6 6-8 8-10 9.5-10 4-7% lng 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 Exploration tail 10-11 15-20 8-12 35-50 2-4 4-8 4-8 9.5-10 <12% Drilling Area Risks: Identified risks in the 2F-18 drilling area include lost circulation in the Lisburne formation. Upon analyzing the risk, the decision is to "reduce or control" the risk to allow for evaluation of the exploration tail is as follows. The Sag River formation will be topset with 7" casing and Parker 245 will drill out a 6-1/8" hole. Logging of Sag River and Ivishak formations will occur prior to drilling into the Lisburne formation. The exploration tail will be cased with a 5" liner if testing the well is warranted. The 9-5/8" and 7" casing shoes will be tested to leak-off or to a maximum of 16 ppg EMW upon drilling 10 foot of new formation. RECEIVEi) ['"iq"; 0 c.-ici9$ Alask¢-. 0it & r:o.~,,.,, ,..,.::~o~,.- ~. C:on~rrnssion KRU 2F-18 Exploration Tail (Gold Hills) PRESSURE INFORMATION AND CASING DESIGN (per 20 AAC 25.005 (c) (3,4) and as required in 20 AAC 25.035 (d)(2)) DISCUSSION The following presents the data used for calculation of the allowable surface pressures (ASP) used for the design and drilling of the 2F-18 Gold Hills well. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressu re Drilling (inches) (ft, TVD) (ppg) (ppg) (psi) (psi) 1 6 1 21 N/A N/A N/A N/A 9-5/8 3138 15.4 8.8 1 375 1363* 7 7700 16.2 10.2 4080 3560* 5 9900 1 6.9 9.3 4800 N/A * Note: 5000 psi BOP equipment is adequate. Expected Maximum Mud Weights: 12-1/4" Surface Hole to 4200/3138" 8-1/2" Intermediate Hole to 11750'/7700' · 6-1/8" Production Hole to 13850'/9900' · 9.8 ppg 10.5 ppg 11.0 ppg Procedure for calculating ASP' ASP calculations are based on anticipated pore pressures in each hole interval and are presented using the following equation' ASP = ((PP x 0.052)- 0.11)D where' ASP = Anticipated Surface Pressure in psi PP = Pore Pressure in ppg (use above mud weights) 0.052 = Conversion Factor from ppg to psi/ft D = True Vertical Depth of Casing Shoe Calculations: 1) Drilling below 9-5/8" Surface Casing: ASP = ( (PP x 0.052)- 0.11) D = ( (10.5 x 0.052) - 0.11) 3138 = 1368 psi 2) Drilling below 7" Surface Casing: ASP = ( (PPx 0.052)- 0.11) D = ( (11 x 0.052)- 0.11) 7700 = 3560 psi KRU 2F-18 Exploration Tail (Gold Hills) PRESSURE ANALYSIS AND PREDICTION (per 20 ACC 25.005 (c) (7) and 20 ACC 25.033 (e)) DISCUSSION: An analysis and prediction of overpressured strata was performed for the 2F-18 Gold Hills well as required by AOGCC regulations. ARCO does not expect to encounter abnormal pressure from any zones. The prediction is based on an evaluation of offset wells KRU 1E-06, W. Sak #1, Colville #1, East Ugnu and Kalubik Creek #1). Attached are the following: Mud weight versus depth graph for these wells. Sonic log interval transit time analysis for KRU 1E-06. Pore pressure, frac pressure & anticipated mud weight graph. There are no shallow hazards (such as shallow gas) expected at 2F-18. There have been 16 wells drilled from KRU 2F pad and shallow gas has not been encountered. Therefore, ARCO requests a waiver from 20 ACC 25.005 (c) (8). Gold Hills 2F Exploration Tail OFFSET MUD WEIGHT DATA 2OOO 4000 6000 8000 10000 1200O 8 9 10 11 12 13 WEIGHT (ppg) 1 i ---e-- West Sak #1 ~ East Ugnu .--~:. -- Kalubik Creek ~ KRU 1 E-06 jt/mac 10/10/96 Gold Hills 2F Exploration Tail -1000 1 ooo i 3000i 5ooo 7000 9000 11000 13000 10 100 1000 SHALE- ITT (ms/ft) data lrom KRU 1E-06 2000, 4000 6OOO 8OOO 10000 12000 6 7 8 9 1011 12131415161718 EMW (ppg) jt/mac 10/10/96 ILLE 2M 3M 3H ALUBI 3G 2T 2Ft 2H 3I ~E E t 3F 2U 2V 2B 2G 3ID 30 3N 3J 1 3B 2N 2X 2C 3K 2F 3C ®ERS 1R lQ 1Y 2Z 2O 2E 1G 1R 1F 1L 1H lB ®iE-O I · NESTS lC 8 1D I ANNIJ_~R PUMPING OPERATIONS WELL KRU 2F-18 Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well or the nearest dedicated disposal well (2M-23). (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 2F-18 surface/intermediate 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 2F-18 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 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 AC)GCC. 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 = 3458 psi The surface and intermediate casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, Inc. Structure : Pad 2F Well : 18(GH) F}eld : Kuparuk River Unit Locallon : North Slope, Alaska D~te plotted: I ~-0ct-96 PI~ E~erence ;s 1KGoM ~'~s)Ve~.tS. C~rd;n~s ~e ~ f~t reference slot S 8.54 DEG E 6467'(T0 TARGET) · **Plane of Proposal*-* JSURFACE LOCATION: J 128' FNL, 1738' FEL SEC. 35, T11N, RgE 600 1200 1800 24O0 3000 5600 4200 48OO 5400 6000 6600 72OO 7800 8400 go00 9600 10200 600 T mB ELEVATION: 138' KOP TVD=300 TMD=300 DEP=O 3.00 BEGIN TURN TO TARGET WD=466 TMD=467 DEP=O ½6.33 11.07 16.64 ~,, 22.43 DLS: 3.00 de(] per 100 ft ~k 28.30 'k 34.22 ~, 40.15 ~. 46.10 ~'~ 52'0;1.02- T/ W SAK SNDS (EST.) TVD=2288 TMD=2900 DEP=1354 2290 TM0=2906 DEP=1560 B/ W SAK SNDS TVD=2938 TMD--5139 DEP=3496 9 5/8~=3138 TMD=5828 DEP---4156 .~.~ - "¥~.oo 52.00 ~.. MAXIMUM ANGLE ~o~.Ooo 73.13 DEG ~°i~°.°oo DLS: 2,00 deg per 1(30 ft 28.00 -' YZo'o 20.00 16.00 12.00 8.00 TARGET - T/ KUP SNDS (EOD) 4.00 TVD=5964 TMD=9??6 DEP=6467 B/ KUP SNDS TVD=6126 TMD=9938 OEP=6467 7" CSG PT TVD=7700 TMD=l1512 OEP:6467 T/ SAG RIVER TVD=7888 TMD=11700 DEP=6467 T/ rV1SHAK TVD=8148 TMD=11960 DEP=6467 T/ LISBURNE 'P/0=9058 TMD=12870 0EP=6467 LISBURNE TO WD=9508 TM0=13320 DEP=6467 PLANNED TD / 5" CSG PT TVD=9908 TMD=15720 DEP=6467 I I i I i i i i i i i i i i i i i i i i 600 ~200 ~800 2400 3000 3600 4200 4800 5400 8000 Vertical Section (feet) -> Azimuth 171.46 with reference 0,00 N, 0.00 E from slot #18 JL i i i 6600 7200 East (feet) -> 600 0 600 1200 I I I I I I I g 5/8 Co 2F-18(6H) R~d lO-Oct-g§(~) 1800 600 0 6O0 12aa 1800 2400 0 .4- ,3000 ~, --4-- 3600 I v 4-2OO 48OO 54Oo 6000 6600 ITARGET LOCATION: J 1244' FNL, 778' FEL SEC. 4, TI ON, R9E TARGET TV0=5964 TMD=9776 DEP=6467 SOUTH 6396 FAST 960 TARGET ANGLE VERTICAL Cre<,t~d by }ones For: J ?RANTIC_kM Dote p[oRed: 11-Oct-g6 Plot Reference ~s 18(Goad Hals) Vers.~/5. Cearclrnotes ore in feet reference slot 1{18. True Vertical Depths~ FS(B (Parker ~245]. ARCO ALASKA, Inc. Structure: Pod 2F Well : 18(GH) Field : Kuporuk River Unit Locofion : North Slope, Alosko <- West (feet) ,320 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 80 ~e~ e ~o 5 ® O0 40 40 ~oo/ o / / ._~oo o 40 1600. 40 ~ 800 / / 1200 j ~00 ~100 19oo ~ , ~-' ~6o / ,, / / 1300 ~ go O0 1300 , 2O0 / 1.o0 / j 500 280 / 2200 / 1300 ~o ,/ ~,~ ~oo 360 /tI X~X 1500 560 25oo ~/ / 1700 400 / -- ~ 400 / 1500~ ~ 1400 i m ~ 440 I i ~o ~oo,/ / ~oo ,. ~soo 2500z ~ ~ ~ ~ %~ i 600 520 / / ~ 1900 ~ 520 560 /~ / ~1 ' ~ ' ~ 2~oo 320 280 240 200 ~ 60 120 80 40 0 40 80 120 160 200 240 280 <- West (feet) 120 120 160 200 Cf) 0 t-' 240 280 .__,. I 32o V C ARCO ALASICA, Inc. Pad 2F Well : 18(GH) slot #18 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 Baker H~ghes INTEG REPORT Your ref : 18(Gold Hills) Vers.~fJ Our ref : prop1585 License : Date printed : 11-0ct-96 Date created : 26-Mar-96 Last revised : 11-0ct-96 Field is centred on nTO 16 18.576,u150 5 56.536 Structure is centred on nTO 16 17.459,w149 50 40.077 SLot Location is nTO 16 16.198,w149 51 30.674 SLot Grid coordinates are N 5948754.438, E 517493.577 Slot local coordinates are 128.00 S 1758.00 W Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Refere~e North is Trw North Report is limited to clearances Less than 500 DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wettpath CLosest approach with 3-D Minimun Distance method Last revised Distance M.D. Diverging from M.D. PGHS <O-7820'>,,12,Pad 2F 4-Feb-92 309.5 300.0 10280.0 PGMS <O-8452'>,,14,Pad 2F 4-Feb-92 72.4 725.0 10140.0 PGHS <O-78~7'>,,13,Pad 2F &-Feb-92 108.1 1325.0 9860.0 PGHS <O-7550'>,,15,Pad 2F 4-Feb-92 14.4 325.0 10:540.0 PGMS <O-7425'>,,16,Pad 2F 4-Feb-92 45.7 20.0 20.0 PGHS <O-6920'>,,1,Pad 2F 4-Feb-92 595.3 20.0 20.0 PGHS <O-7630'>,,2,Pad 2F 4-Feb-92 654.4 350.0 350.0 PGMS <O-8075'>,,3,Pad 2F 4-Feb-92 714.8 20.0 20.0 PGMS <O-8050'>,,4,Pad 2F 4-Feb-92 774.7 20.0 20.0 PGMS <O-9470'>,,6,Pad 2F 4-Feb-92 768.4 20.0 20.0 PGMS <O-9055'>,,7,Pad 2F 4-Feb-9Z 713.1 ZO.O 20.0 Pr, MS <O-637'5'>,,8,Ped 2F 4-Feb-92 658.1 240.0 240.0 PGMS <O-6560'>,,9,Pad 2F 4-Feb-92 282.7 300.0 10080.0 PGMS <O-8725'>,,lO,Pad 2F 4-Feb-92 279.1 300.0 300.0 PGMS <O-10160'>,,11,Pad 2F 4-Feb-92 289.3 20.0 20.0 PraMS <O-7*580'>,,5,Pad 2F 4-Feb-92 823.0 325.0 325.0 2F-H Version #3,,2F-H,Pad 2F 11-0ct-96 149.1 280.0 280.0 2F-A Version #4,,2F-A,Pad 2F 11-0ct-96 61.0 350.0 350.0 Casing Design / Cement Calculations 14-0ct-96 Surface lead' Surface tail: Intermediate tail' Top West Sak, TMD = 2,900 ft Design lead bottom 500 ft above the Top of West Sak = 2,400 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 801 cf Excess factor = 150% Cement volume required = 2,003 cf Yield for Permafrost Cmt = 1.94 Cement volume required =1 1,030 sxJ TMD shoe = 5,827 ft (surface TD - 500' above West Sak) * (Annulus area) = 1,073 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 1,107 cf Excess factor = 15% Cement volume required = 1,274 cf Yield for Class G cmt = 1.15 Cement volume required =1 1,110 sxJ TMD = 11,511 ft Top of Target, TMD = 9,900 ft Want TOC 500' above top of target = 9,400 ft 7" Annulus area (9" Hole) = 0.1745 Cement outside of casing= 368 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt - 386 cf Excess factor = 15% Cement volume required = 443 cf Yield for Class G cmt = 1.19 Cement volume required =1 370 sxI Production Liner tail' TM D = 13,720 ft Top of Liner, MD = 11,500 ft 5" Annulus area (7" Hole) = 0.1309 Cement outside of casing= 289 cf Cement in csg x csg annulus= 0.0785 Cement in Lap= 1 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.0997 Cmt required in casing = 8 cf Total cmt = 298 cf Excess factor = 15% Cement volume required = 343 cf Yield for Class G cmt = 1.19 Cement volume required =1 290 sxI < 7 , 6 5 13 5/8" 5000 PS! 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. :~ 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. I 1. 16" - 2000 PSi STARTING HEAD 2. 11' o 3000 PSI CASING HEAD 3. 11' - 3(XX:) PSI X 13.5,/8" - 5(X~ PSI SPACER SPOOL 4. 13..5/8' - 5000 PSI PIPE AMS 5. 13,.5/8". 5000 PS! DRLG SP(:X::X_ W/ CHOKE AND KILL UNES 6. 13-5/8" - 5000 PSI DOIJEiLE RNVI W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR BOPSTACKTEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. ~_ 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. BI. EED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PS! AND 3003 PSI AS IN STEP 4. ~UE TESTING ALL VALVES, MNES, AND CHOKES WITH A 250 PS! LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTrOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(XX) PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF FIOI_F_ CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. B/FFD TO ZERO PSI. 1~ OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD ANO LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING PosmoN. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COC~(S AND INSIDE BOP TO 30(]0 PSI WITH KOOMEY PUMP. 13~ RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. ~ WILL A~ATE ~1/2" TO 5-1/2" OR 5" TO 7' PIPE ODS AS APPROPRIATE. KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 6 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANOE & 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~)N 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. 2o" - 2000 PSI ANNULAR PREVENTER. DKP 14/9/94 · WELL PERMIT CHECKLIST aev redri, n wa,bo,, ADMINISTRATION REM~KS · P e~it Le~ numar ~pmpda~ ................... (. Unique w~ n~e ~d numar ................ W~l I~ in a defin~ ~I .................. Well io~t~ pro~r dis~ ~om ddg un~ ~un~ ..... Well I~ pm~r d~ ~m o~er ~ ........ N ~ ~/~ /Z~ :~~ ~ ~~ ~~/~/~.. , ' GkOLOGY .... . 2_ 3. 4. 5. 6. 7. 8. 9. 10. 11. 12_ 13. 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 conserva~on order Permit can be issued wi~out administrative approval... Can permit be approved before 1,5-day wail ....... Conductor string provided .................. .(,~ N 15. Surface casing protects ail known USDWs ..........'"' "' 16. CMl' vol adequate to circulate on conductor & surf csg . . .~/,'_N 17. CMT vol adequate to fie-in long string to surf csg ...... .'~.~_~.(~ 18. CMT will cover all known produc~ve horizons ......... ~N. 19. Casing designs adequate for C, T, B & permafrost. ..... 20. Adequate tankage or reserve pit. ............... ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved... 22. Adequate wellbore sepam~on proposed ............ 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schen'~tic & equip list adequate .... 25. BOPEs adequate ........................ 26. BOPE press rating adequate; test to ,~g:rC) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ...... 28. Work will occur wi~out operation shutdown. 29. is presence of H2S gas probable .............. 30. Permit can be issued w/o hydrogen sulfide measures... 31. Dots presented on potenlJai overpressure zones ...... 32_ Seismic anaJysis of shallow gas zones ............. 33. Seabed condilJon survey (if off-shore) 34. Comact name/phone for weekly progress repo~ .. .... lexploratory antyJ N ., GEOLOGY: RP~, ENGINEERING: COMMISSION: BEW~ d/,,¢ DW TAB Comments/instructions: HOW4~- A.'~-OR~ rev 4/96 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 Wed Apr 23 10:13:54 1997 Reel Header Service name ............. LISTPE Date ..................... 97/04/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/04/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COM2ANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-60201 P.ROBERTS D. LUTRICK 2F-18 500292272000 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 23-APR-97 MWD RUN 4 AK-MM-60201 P.ROBERTS B. MORRISON MWD RUN 5 AK-M>4-60201 P. ROBERTS G. WHITLOCK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 6 AK-MM-60201 P.ROBERTS G. WHITLOCK 33 llN 09E 128 1738 .00 138.00 M CROFILM[g Date, GROUND~ LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 96.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 5614.0 8.500 7.000 9140.0 6.125 9715.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 5. THE DATA FROM 5605'MD TO 5700'MD IS THE COMMON BOREHOLE SECTION OF 2F-18PB1 AND 2F-18. THE COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO DENSITY (SLD) DATA WAS NOT RECORDED UNTIL 9100'MD DURING MWD RUN 3. THIS DATA IS ONLY PRESENTED ON THE LOGS OF 2F-18PB1. 6. MWD RUNS 4 THROUGH 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISITIVITY PHASE-4 (EWR4). 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9716'MD, 6385'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 ....... 97/04/23 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 SUM~uXRY PBU TOOL CODE START DEPTH STOP DEPTH GR 5604.5 9663.0 ROP 5604.5 9716.5 FET 5605.0 9670.0 RPD 5605.0 9670.0 RPM 5605.0 9670.0 RPS 5605.0 9670.0 RPX 5605.0 9670.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 5604 5 9142 9144 9146 9147 9152 9153 9155.5 9156.5 9160.0 9161 5 9163 5 9166 0 9169 0 9171 0 9179 5 9180 5 9182 0 9183 5 9192 5 9199 5 9201 5 9203 5 9206 0 9218 5 9220 0 9229.5 9231.0 9234.5 9237.0 9238.5 9239.5 9240.5 9242.0 9246.0 9248.0 9250.5 9253.5 9256.5 9258.0 9261.5 92 65.0 9270.0 9273.0 9286.0 9288.0 9294.5 9297.0 9300.0 9314.5 9316.0 GR 5605 0 9143 0 9145 0 9148 0 9149 5 9154 0 9156 0 9158 0 9159.5 9162.5 9163.0 9165.0 9168.0 9170.0 9172.0 9181.0 9182.5 9185.0 9186.0 9195.5 9201.0 9203.5 9205.5 9207.0 9220.0 9221.0 9230.0 9232.0 9234.5 9236.0 9238.5 9241.5 9242.0 9243.0 9246 0 9249 0 9250 5 9254 0 9257 0 9260 5 9262 5 92 65 5 9271.0 9274 5 9286 5 9289 5 9294 0 9298 5 9301 0 9315 0 9315 5 EQUIVALENT UNSHIFTED DEPTH 9323 9326 9327 9329 9333 9343 9361 9364 9367 9369 9371 9373 9375 9378 9381 9383 9384 9385 9386 9388 9394 9396 9398 9402 9404 9406 9409 9452 9454 9456 9459 9468 9470 9472 9475 9485 9486 9487 9624 9627 9634 9636 9641 9716 $ 5 5 5 5 5 5 .0 5 0 0 5 0 0 .5 .0 .5 .0 .0 .5 .5 .5 .0 .0 .0 0 5 0 0 0 5 0 5 5 5 0 0 5 5 5 5 5 0 0 5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: 9325 9327 9328 9331 9334 9343 9361 9364 9367 9369 9371 9372 9375 9378 9380 9382 9384 9385 9387 9389 9394 9395 9397 9399 9402 9405 9408 9452 9454 9457 9459 9470 9471 9472 9475 9484 9485 9486 9624 9627 9635 9635 9640 9716 .0 .5 .0 0 0 5 0 5 5 5 5 5 5 5 5 5 0 BIT RUN NO MERGE TOP MERGE BASE 3 5605.0 5700.0 4 5700.0 7703.0 5 7703.0 9141.0 6 9141.0 9716.0 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 5 0 0 0 5 5 5 5 5 0 0 5 5 5 0 0 5 .5 .5 .5 .5 .5 .0 .0 .5 .5 .0 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD AAPI 4 1 68 MWD OHM~ 4 1 68 MWD OHMS4 4 1 68 MWD 0H~94 4 1 68 MWD OHM~ 4 1 68 MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 5604.5 9716.5 7660.5 8225 ROP 9.8361 641.964 154.848 8225 GR 25.8412 421.893 106.456 8118 RPX 0.1901 55.6378 3.1362 8131 RPS 0.0824 2000 3.7109 8131 RPM 0.085 2000 24.7028 8131 RPD 0.05 2000 32.0138 8131 FET 0.2592 78.4011 3.78578 8131 First Reading 5604.5 5604.5 5604.5 5605 5605 5605 5605 5605 Last Reading 9716.5 9716.5 9663 9670 9670 9670 9670 9670 First Reading For Entire File .......... 5604.5 Last Reading For Entire File ........... 9716.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 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 ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR ROP FET RPD RPM RPS RPX $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5605 0 5605 0 5605 5 5605 5 5605 5 5605 5 5605.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT)~ BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5699 5 5699 5 5699 5 5699 5 5699 5 5699 5 5699.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA24MA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT}: BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: ~gD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL ~uXTRIX: 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 29-DEC-96 ISC 4.88 CIM 5.46 MEMORY 5700.0 5605.0 5700.0 2.8 68.7 TOOL NUMBER P0616CNGRD6 P0616CNGRD6 P0616CNGRD6 8.500 8.5 LSND 11.00 57.0 8.0 5OO 3.8 .000 .000 .000 .000 48.3 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 DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD 3 FT/H 4 1 68 MWD 3 AAPI 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OHMS4 4 1 68 MWD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 5605 5699.5 5652.25 190 ROP 16.176 641.964 323.269 190 GR 45.578 91.504 76.1991 190 RPX 1.358 55.638 9.04586 189 RPS 1.058 2000 29.9664 189 RPM 3.791 2000 151.413 189 RPD 4.13 2000 192.468 189 FET 58.627 64.115 60.2656 189 First Reading 5605 5605 5605 5605.5 5605.5 5605.5 5605.5 5605.5 Last Reading 5699 5 5699 5 5699 5 5699 5 5699 5 5699 5 5699 5 5699 5 First Reading For Entire File .......... 5605 Last Reading For Entire File ........... 5699.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR ROP FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5605 0 5605 0 5605 0 5605 0 5605 0 5605 0 5605 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7642 5 7642 5 7642 5 7642 5 7649 5 7702 5 7642 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH]~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MTkTRIX: 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 10-JAN-97 ISC 4.88 CIM 5.46 MEMORY 7703.0 5700.0 7703.0 28.8 68.9 TOOL NUMBER P0626CRG6 P0626CRG6 8.500 8.5 LSND 11.00 58.0 9.5 6OO 7.0 .000 .000 .000 .000 -17.7 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 DEPT GR RPX RPS RPM RPD ROP FET Service Order Units Size Nsam Rep FT 4 1 68 MWD 4 AAPI 4 1 68 MWD 4 OHM}4 4 1 68 MWD 4 OHM~ 4 1 68 MWD 4 OHN/~ 4 1 68 MWD 4 OHN/~ 4 1 68 MWD 4 FT/H 4 1 68 MWD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 5605 7702.5 6653.75 4196 GR 25.8412 185.551 93.7317 4090 RPX 0.2185 14.694 3.06649 4076 RPS 0.356 2000 4.19591 4076 RPM 1.5442 2000 11.5914 4076 RPD 0.05 2000 11.7353 4076 ROP 9.8361 640.052 189.093 4196 FET 0.1792 5.1496 0.961133 4075 First Reading 5605 5605 5605 5605 5605 5605 5605 5605.5 Last Reading 7702.5 7649.5 7642.5 7642.5 7642.5 7642.5 7702.5 7642.5 First Reading For Entire File .......... 5605 Last Reading For Entire File ........... 7702.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate [iles. BIT RUN NUMBER: 5 DEPTH INCREMEh!T: FILE S UM]VL~RY .5000 VENDOR TOOL CODE START DEPTH FET 7643.5 RPD 7643.5 RPM 7643.5 RPS 7643.5 RPX 7643.5 GR 7651.5 ROP 7704.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9081 0 9081 0 9081 0 9081 0 9081 0 9088 0 9141 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS) 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 12-JAN-97 ISC 4.88 CIM 5.46 MEMORY 9141.0 7703.0 9141.0 26.7 28.8 TOOL NUMBER P0626CRG6 P0626CRG6 8.500 8.5 LSND 11.00 58O.O 9.5 600 7.0 3.100 1.808 2.600 4.200 48.9 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 GR MWD 5 AAPI 4 1 68 4 2 RPX MWD 5 OHN~ 4 1 68 8 3 RPS MWD 5 OHHM 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD MWD 5 OHMM 4 1 68 20 6 ROP MWD 5 FT/H 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 7643.5 9141 8392.25 2996 GR 57.1129 421.893 128.808 2874 RPX 0.6869 5.9541 2.53077 2876 RPS 0.6828 5.8968 2.5482 2876 RPM 0.67 5.4616 2.55823 2876 RPD 0.7299 5.6545 2.66026 2876 ROP 29.3531' 344.861 138.872 2875 FET 0.2622 13.0334 1.64831 2876 First Reading 7643 5 7651 5 7643 5 7643 5 7643 5 7643 5 7704 7643.5 Last Reading 9141 9088 9081 9081 9081 9081 9141 9081 First Reading For Entire File .......... 7643.5 Last Reading For Entire File ........... 9141 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPM RPS RPX RPD ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8982 0 8988 0 8988 5 8988 5 8988 5 8989 0 9036 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9662.5 9669.5 9669.5 9669.5 9669.5 9669.5 9716.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL I~ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 16-JAN-97 ISC 4.88 CIM 5.46 MEMORY 9716.0 9141.0 9716.0 25.4 26.9 TOOL NUMBER P0588SP4 P0588SP4 6.130 6.1 LSND 12.20 60.0 9.0 2000 4.2 1.400 .720 1.300 1.450 60.4 .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 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 6 AAPI 4 1 68 MWD 6 OHMM 4 1 68 MWD 6 OHMM 4 1 68 MWD 6 OHMM 4 1 68 MWD 6 OHMM 4 1 68 MWD 6 FT/H 4 1 68 MWD 6 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 8982 9716 9349 GR 27.068 235.37 97.1423 RPX 0.1901 45.7096 4.17533 RPS 0.0824 281.567 4.96453 RPM 0.085 2000 267.425 RPD 0.05' 2000 408.144 ROP 15.6748 609.541 123.452 FET 0.4848 78.4011 18.2472 First Last Nsam Reading Reading 1469 8982 9716 1362 8982 9662.5 1364 8988 9669.5 1363 8988.5 9669.5 1363 8988.5 9669.5 1362 8989 9669.5 1361 9036 9716 1364 8988 9669.5 First Reading For Entire File .......... 8982 Last Reading For Entire File ........... 9716 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/04/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/04/23 Scientific Technical Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Scientific Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Apr 22 16:48:48 1997 Reel Header Service name ............. LISTPE Date ..................... 97/04/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/04/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER 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 MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MM-60201 P.ROBERTS D. LUTRICK 1ST STRING 2F-18 PB1 500292272070 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 22-APR-97 33 llN 09E 128 1738 .00 138.00 96.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS WERE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) DATA IS PRESENTED ON A SEPERATE LOG. 5. CIRCULATED FOR APPROX. 15 HOURS AT 9521'MD, 5739'TVD TO RAISE MUD WEIGHT TO 10.6 PPG. 6. CIRCULATED FOR APPROX. 14 HOURS AT 9505'MD, 5993'TVD TO RAISE MUD WEIGHT TO 11.1 PPG. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9591'MD, 6079'TVD. 8. THE WELL WAS DRILLED FROM 9591'MD, TO 9710'MD WITHOUT MWD AND PLUGGED BACK TO THE 9 5/8" CASING SHOE FOR A REDRILL DUE TO DRILLING CONDITIONS. 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. SPSF = SMOOTHED COMPENSATED NEUTON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 500 PPM. MUD WEIGHT = 9.8 - 11.1 PPG. FORMATION WATER SALINITY= 14545 PPM. LITHOLOGY = SANDSTONE. $ 12.250 9.625 5614.0 8.500 9591.0 File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/22 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. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH FET 5605.0 GR 5605.0 ROP 5605.0 RPD 5605.5 RPM 5605.5 RPS 5605.5 RPX 5605.5 PEF 9100.5 DRHO 9100.5 RHOB 9100.5 FCNT 9100.5 NCNT 9100.5 NPHI 9100.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 9509 0 9539 0 9591 0 9509 5 9509 5 9509 5 9509 5 9528 5 9528 0 9528 0 9519 0 9519.0 9519.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 5605.0 9591.0 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 GR MWD AAPI 4 1 68 4 2 RPM MWD CHM~4 4 1 68 8 3 ROP MWD FT/H 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 RPS MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RHOB MWD G/CC 4 1 68 28 8 DRHO MWD G/CC 4 1 68 32 9 PEF MWD BARN 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 NPHI MWD P.U. 4 1 68 44 12 FCNT MWD NCNT MWD CNTS 4 1 68 CNT S 4 1 68 48 52 13 14 Name DEPT GR RPM ROP RPX RPS RPD RHOB DRHO PEF FET NPHI FCNT NCNT Mi 56O 45.57 0 899 15 373 0 887 0 901 0 955 2 083 0.00 2.283 0.210 28.389 412.25 203 n Max Mean 5 9591 7598 8 368.032 106.456 9 2000 6.7926 9 1229.36 255. 966 6 55. 6378 3. 35101 8 2000 3.87417 3 2000 7.84115 3 3. 0365 2. 39547 1 0.453 0.0642827 5 19. 5276 4. 82092 9 64. 1146 2. 89812 9 81. 7622 68. 9949 7 959 568. 662 2 3512.58 2401.22 Nsam 7973 7869 7809 7973 7809 7809 7809 856 856 685 7809 838 838 838 First Reading 5605 5605 56O5.5 5605 5605.5 5605.5 5605.5 9100.5 9100.5 9100.5 5605 9100.5 9100.5 9100.5 Last Reading 9591 9539 9509.5 9591 9509.5 9509.5 9509.5 9528 9528 9528.5 9509 9519 9519 9519 First Reading For Entire File .......... 5605 Last Reading For Entire File ........... 9591 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/22 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 ....... 97/04/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 5605.0 GR 5605.0 ROP 5605.0 RFD 5605.5 RPM 5605.5 STOP DEPTH 9509.0 9539.0 9591.0 9509.5 9509.5 RPS 5605 5 RPX 5605 5 PEF 9100 5 DRHO 9100 5 RHOB 9100 5 FCNT 9100 5 NCNT 9100 5 NPHI 9100 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9509 5 9509 5 9528 5 9528 0 9528 0 9519 0 9519 0 9519 0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 29-DEC-96 ISC 4.88 ClM 5.46 MEMORY 9591.0 5605.0 9591.0 2.8 68.7 TOOL NUMBER P0616CNGRD6 P0616CNGRD6 P0616CNGRD6 P0616CNGRD6 8.500 8.5 LSND 11.00 57.0 8.0 5O0 3.8 ,000 .000 .000 .000 48.3 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 DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT RHOB NCNT DP. HO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD 3 FT/H 4 1 68 MWD 3 AAPI 4 1 68 MWD 3 OHMM 4 1 68 MWD 3 OH/~4 4 1 68 MWD 3 OHMS4 4 1 68 MWD 3 OHMS4 4 1 68 MWD 3 HOUR 4 1 68 MWD 3 P.U. 4 1 68 MWD 3 CNTS 4 1 68 MWD 3 G/CC 4 1 68 MWD 3 CNTS 4 1 68 MWD 3 G/CC 4 1 68 MWD 3 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 5605 9591 7598 ROP 15.374 1229.36 255.966 GR 45.578 368.033 106.456 RPX 0.888 55.638 3.35102 RPS 0.902 2000 3.87416 RPM 0.9 2000 6.7926 RPD 0.955 2000 7.84115 FET 0.211 64.115 2.89811 NPHI 28.39 81.762 68.9949 FCNT 412.257 959 568.662 RHOB 2.083 3.036 2.39547 NCNT 2032 3512.58 2401.22 DRHO 0.001 0.453 0.0642827 PEF 2.2835 19.5276 4.82092 Nsam 7973 7973 7869 7809 7809 7809 7809 7809 838 856 838 856 685 First Reading 5605 5605 5605 5605.5 5605.5 5605.5 5605.5 5605 9100 5 9100 5 9100 5 9100 5 9100 5 9100 5 Last Reading 9591 9591 9539 9509.5 9509.5 9509.5 9509.5 9509 9519 9519 9528 9519 9528 9528.5 First Reading For Entire File .......... 5605 Last Reading For Entire File ........... 9591 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/04/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Services Writing Reel Trailer Service name ............. LISTPE Date ..................... 97/04/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File FE[B 1 ~ 1997 ,~tqchor~le, * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... .___ . COMPANY NAME : ARCO ALASKA, INC. WELL NAIVE : 2F- 18 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292272000 REFERENCE NO : 97037 M CROFILMED LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE · 97/01/31 ORIGIN · FLIC REEL NAME : 97037 CONTINUATION # : PREVIOUS REEL : COfCff4F~f . ARCO ALASKA INC, 2F-18, KUPARUK, API #50-029-22720-00 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE · 97/01/31 ORIGIN · FLIC TAPE NAME : 97037 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 2F-18, KUPARUK, API #50-029-22720-00 TAPE HEADER KUPARUK RIVER UNIT OPEN HOLE WIRELINE 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 : RUN 1 ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING PRODUCTION STRING 2F - 18 500292272000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 31-JAN-97 RUN 2 97037 BAILEY GUY WHITLOCK RUN 3 33 liN 9E 128 1738 138.00 97.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 9104.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 REMARKS: This file contains the open hole edit on ARCO ALASKA well 2F-18. This file contains a main and repeat pass. No depth adjustments were made to this data. This SDN/GR will be the primary depth control for subsequent logging. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVUMBER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE SDN CNTG $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (f4~ASURED DEPTH) START DEPTH STOP DEPTH ..................... 9709.0 9140.0 9709.0 9140.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: This file contains the LDWG main pass open hole data. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN CNTG .............. RUN NO. PASS NO. ............... MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100665 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 100665 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 100665 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 100665 O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDN IN 100665 O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI 100665 O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDN LB 100665 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 100665 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 100665 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 100665 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 100665 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 100665 O0 000 O0 0 1 1 1 4 68 0000000000 TNPH CNTG PU-S 100665 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 100665 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 100665 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 100665 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 100665 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 100665 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: DEPT. 9709. 000 RHOB. SDN CALI. SDN 6.078 GR. SDN ENRA. CNTG 4.619 CFEC. CNTG TNPH. CNTG 42.02 6 CRAT. CNTG CNTC. CNTG 2538. O14 CFTC. CNTG DEPT. 9140.000 RHOB.SDN CALI.SDN 6.527 GR.SDN ENRA.CNTG 5.575 CFEC. CNTG TNPH. CNTG 56.663 CRAT. CNTG CNTC. CNTG 1707.391 CFTC. CNTG 2.450 DRHO.SDN 97.438 TENS.SDN 737.066 CNEC. CNTG 3.397 FCNT. CNTG 759.402 2.317 DRHO.SDN 69.688 TENS.SDN 510.087 CNEC. CNTG 4.464 FCNT. CNTG 404.941 0.003 PEF. SDN 5270.000 ENPH. CNTG 3404.812 NPHI.CNTG 2681.806 NCNT. CNTG -0.504 PEF. SDN 3975.000 ENPH. CNTG 2843.854 NPHI.CNTG 1894.909 NCNT. CNTG 7.043 30.907 44.278 748.522 9.273 40.845 63.322 401.201 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER: 2 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH SDN 9709.0 9140.0 CNTG 9709.0 9140.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ SDN CNTG RUN NO. PASS NO. MERGE TOP MERGE BASE ................... REMARKS: This file contains the LDWG Main pass logged in casing. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100665 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 100665 O0 000 O0 0 2 1 1 4 68 0000000000 E1VRA CNTG 100665 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 100665 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 100665 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 100665 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH CNTG PU-S 100665 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 100665 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CN~fG CPS 100665 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) FCNT CNTG CPS 100665 CNTC CNTG CPS 100665 CFTC CNTG CPS 100665 CALI SDN IN 100665 TENS SDN LB 100665 GRCH SDN GAPI 100665 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9140.000 ENPH. CNTG 40.845 ENRA.CNTG 5.575 CFEC. CNTG CNEC. CNTG 2843.854 NPHI.CNTG 63.322 TNPH. CNTG 56.663 CRAT. CNTG NCNT. CNTG 1894.909 FCNT. CNTG 401.201 CNTC. CNTG 1707.391 CFTC. CNTG CALI.SDN 6.527 TENS.SDN 3975.000 GRCH. SDN 69.688 DEPT. 8976.000 ENPH. CNTG 45.704 ENRA.CNTG 5.978 CFEC. CNTG CNEC. CNTG 2608.117 NPHI. CNTG 60.829 TNPH. CNTG 54.251 CRAT. CNTG NCNT. CNTG 1663.716 FCNT. CNTG 376.272 CNTC. CNTG 1604.438 CFTC. CNTG CALI.SDN 6.285 TENS. SDN 4005.000 GRCH. SDN 176.500 510.087 4.464 404.941 436.259 4. 313 391.366 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER 3 RAW OPEN HOLEM_AIN PASS LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 7 Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREmENT: 0.5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH LDT 9735.5 CNTG 9735.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 9140.0 9140.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TCC TCC GR CNTG LDT LDT DITE $ TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE GANk~A RAY COMPENSATED NEUTRON LITHOLOGY DENSITY LITHOLOGY DENSITY PHASOR INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (Otflv~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : 16-JAN-97 CP 44.2 1100 17-JAN-97 1630 16-JAN-97 9715.0 9715.0 9140.0 9706.0 1800.0 TOOL NUMBER TCM-AB 217 TCC SGC-SA CNC-GA 63 NSC-E 789 DRS-C 4824 DITE 276 6.125 9104.0 LNS 13.10 51.0 8.5 185.0 10. 210 65.0 1.410 65.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: MUD CAKE AT (MT): MUD CAKE AT (BHT) : 91. 700 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: MAIN PASS RAW OPEN HOLE DATA USED PRIMARY DEPTH CONTROL. HEADING INFORMATION SUPPLIED BY CLIENT. $ LIS FORMAT DATA 65.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 156 4 66 1 5 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100665 O0 000 O0 0 3 1 1 4 68 0000000000 DPHI LDT PU 100665 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LDT G/C3 100665 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LDT G/C3 100665 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LDT BN/E 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) QLS LDT 100665 O0 000 O0 0 3 1 1 4 68 0000000000 QSS LDT 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LS LDT CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LU LDT CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LL LDT CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LITHLDT CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 SSi LDT CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 SS2 LDT CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LSHVLDT V 100665 O0 000 O0 0 3 1 1 4 68 0000000000 SSHVLDT V 100665 O0 000 O0 0 3 1 1 4 68 0000000000 S1RHLDT G/C3 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LSRHLDT G/C3 100665 O0 000 O0 0 3 1 1 4 68 0000000000 LURHLDT G/C3 100665 O0 000 O0 0 3 1 1 4 68 0000000000 GR LDT GAPI 100665 O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN 100665 O0 000 O0 0 3 1 1 4 68 0000000000 TENS LDT LB 100665 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU 100665 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 100665 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 RCEF CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 RCEN CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU 100665 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CNTG PU 100665 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CNTG 100665 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR CNTG 100665 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR CNTG PU 100665 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 100665 O0 000 O0 0 3 1 1 4 68 0000000000 MTEM CNTG DEGF 100665 O0 000 O0 0 3 1 1 4 68 0000000000 MRES CNTG 0H~100665 O0 000 O0 0 3 1 1 4 68 0000000000 HTEN CNTG LB 100665 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9733 . 500 DPHI. LDT PEF. LDT 17. 750 QLS. LDT LU. LDT 331. 000 LL. LDT SS2. LDT 295. 750 LSHV. LDT LSRH. LDT 2. 432 LURH. LDT TENS.LDT 2250. 000 ENPH. CNTG CNEC. CNTG 3389. 161 RCEF. CNTG TNPH. CNTG 42.040 TNRA. CNTG R CNT . CNTG 2681. 806 R CFT . CNTG MTEM. CNTG 145. 344 MIRES. CNTG 13 217 -0 085 154 125 1572 000 2 420 29 481 757.853 3.397 748.522 0.942 RHOB.LDT 2. 432 DRHO.LDT QSS. LDT O. 066 LS. LDT LITH. LDT 46. 969 SSI. LDT SSHV. LDT 1620. 000 S1RH. LDT GR. LDT 97. 438 CALI. LDT ENRA. CNTG 4. 465 CFEC. CNTG RCEN. CNTG 3073. 222 NPHI. CNTG R TNR. CNTG 3.506 NPOR. CNTG CNTC. CNTG 2538. 686 CFTC. CNTG HTEN. CNTG 205. 250 0.005 319.500 243.750 2.412 6.125 759.082 44.538 42.040 759.398 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 10 DEPT. 9140 PEF. LDT 9 LU. LDT 177 SS2. LDT 142 LSRH. LDT 2 TENS . LDT 3975 CNEC. CNTG 2843 TNPH. CNTG 56 RCNT. CNTG 1894 MTEM. CNTG 134 000 DPHI.LDT 273 QLS . LDT 625 LL. LDT 750 LSHV. LDT 824 LURH. LDT 000 ENPH. CNTG 854 RCEF. CNTG 663 TNRA. CNTG .909 RCFT. CNTG · 825 MRES. CNTG 20.164 RHOB. LDT -0. 033 QSS. LDT 79.375 LITH. LDT 1581. 000 SSHV. LDT 2.846 GR. LDT 40. 845 ENRA . CNTG 547. 332 RCEN. CNTG 4. 464 RTNR. CNTG 401.2 O1 CNTC . CNTG O . 969 HTEN. CNTG 2.317 DRHO. LDT -0.047 LS.LDT 16.516 SSi. LDT 1635. 000 S1RH. LDT 69. 688 CALI. LDT 5. 575 CFEC. CNTG 2806.814 NPHI. CNTG 4. 900 NPOR. CNTG 1707. 391 CFTC. CNTG 864. 000 -0 504 168 125 104 938 3 896 6 527 510 087 63 322 53 777 404.941 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .003 SERVICE : FLIC VERSION · 0 O1 CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~VARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... LDT 9735.5 9140.0 CNTG 9735.5 9140.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 11 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... TCC TCC GR CNTG LDT LDT DITE $ TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON LITHOLOGY DENSITY LITHOLOGY DENSITY PHASOR INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) '. DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 16-JAN-97 CP 44.2 1100 17-JAN-97 1630 16-JAN-97 9715.0 9715.0 9140.0 9706.0 1800.0 TOOL NUMBER TCM-AB 217 TCC SGC-SA CNC-GA 63 NSC-E 789 DRS-C 4824 DITE 276 6.125 9104.0 BOREHOLE CONDITIONS MUD TYPE: LNS MUD DENSITY (LB/G): 13.10 MUD VISCOSITY (S) : 51.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 185.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) '. MUD FILTRATE AT (MT): 1.410 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 10.210 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 91. 700 TOOL STANDOFF (IN): EPITHERMAL SANDSTONE 2.65 1.0 RAW REPEAT OPEN HOLE DATA. USED PRIMARY DEPTH CONTROL. H~ING INFORMATION SUPPLIED BY CLIENT. $ REMARKS: 65.0 65.0 65.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 11 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... TCC TCC GR CNTG LDT LDT DITE $ TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON LITHOLOGY DENSITY LITHOLOGY DENSITY PHASOR INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 16-JAN-97 CP 44.2 1100 17-JAN-97 1630 16-JAN-97 9715.0 9715.0 9140.0 9706.0 1800.0 TOOL NUMBER TCM-AB 217 TCC SG C - SA CNC-GA 63 NSC-E 789 DRS-C 4824 DITE 276 6.125 9104.0 91.700 BOREHOLE CONDITIONS MUD TYPE '. LNS MUD DENSITY (LB/G): 13.10 MUD VISCOSITY (S) : 51.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 185.0 RESISTIVITY (OHtB~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 10.210 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 1. 410 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : EPITHERMAL SANDSTONE 2.65 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 1.0 TOOL STANDOFF (IN): REMARKS: RAW REPEAT OPEN HOLE DATA. USED PRIMARY DEPTH CONTROL. HEADING INFORMATION SUPPLIED BY CLIENT. $ 65.0 65. 0 65.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 12 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 156 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 100665 O0 000 O0 0 4 1 1 4 68 0000000000 DPHILDT PU 100665 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LDT G/C3 100665 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LDT G/C3 100665 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LDT BN/E 100665 O0 000 O0 0 4 1 1 4 68 0000000000 QLS LDT 100665 O0 000 O0 0 4 1 1 4 68 0000000000 QSS LDT 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LS LDT CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LU LDT CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LL LDT CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LITHLDT CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 SSi LDT CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 SS2 LDT CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LSHVLDT V 100665 O0 000 O0 0 4 1 1 4 68 0000000000 SSHVLDT V 100665 O0 000 O0 0 4 1 1 4 68 0000000000 S1RHLDT G/C3 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LSRHLDT G/C3 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LURHLDT G/C3 100665 O0 000 O0 0 4 1 1 4 68 0000000000 CR LDT CAPI 100665 O0 000 O0 0 4 1 1 4 68 0000000000 CALI LDT IN 100665 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 13 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS LDT LB 100665 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU 100665 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNTG 100665 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 RCEF CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 RCEN CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU 100665 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH CNTG PU 100665 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNTG 100665 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR CNTG 100665 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR CNTG PU 100665 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS 100665 O0 000 O0 0 4 1 1 4 68 0000000000 MTE~ CNTG DEGF 100665 O0 000 O0 0 4 1 1 4 68 0000000000 MRES CNTG OH~4~ 100665 O0 000 O0 0 4 1 1 4 68 0000000000 HTEN CNTG LB 100665 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9727.000 DPHI.LDT 12.669 RHOB.LDT 2.441 DRHO.LDT PEF. LDT 21.391 QLS.LDT -0.037 QSS.LDT 0.098 LS.LDT LU. LDT 312.500 LL.LDT 156.125 LITH. LDT 38.563 SS1.LDT SS2.LDT 286.000 LSHV. LDT 1579.000 SSHV. LDT 1630.000 S1RH. LDT LSRH. LDT 2.438 LURH.LDT 2.455 GR.LDT 106.938 CALI.LDT TENS.LDT 1555.000 ENPH. CNTG 34.432 ENRA.CNTG 4.883 CFEC. CNTG CNEC. CNTG 3440.702 RCEF. CNTG 703.526 RCEN. CNTG 3119.958 NPHI.CNTG TNPH. CNTG 42.923 TNRA. CNTG 3.448 RTNR.CNTG 3.558 NPOR.CNTG RCNT. CNTG 2903.523 RCFT. CNTC 797.040 CNTC. CNTG 2748.571 CFTC. CNTG MTE~.CNTG 148.100 MRES. CNTG 0.916 HTEN. CNTG 205.125 0.007 312.250 244.875 2.410 6.125 704.668 48.743 42.923 808.621 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 14 **** FILE H~ER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~Y VENDOR TOOL CODE START DEPTH LDT 9140.0 CNTG 9140. 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH .......... 8989.5 8989.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TCC TCC GR CNTG LDT LDT DITE $ TELEMETRY CARTRIDGE TELEMETRY CARTRIDGE GAlV~VA RAY COMPENSATED NEUTRON LITHOLOGY DENSITY LITHOLOGY DENSITY PHASOR INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS 16-JAN-97 CP 44.2 1100 17-JAN-97 1630 16-JAN-97 9715.0 9715.0 9140.0 9706.0 1800.0 TOOL NUMBER TCM-AB 217 TCC SGC-SA CNC-GA 63 NSC-E 789 DRS-C 4824 DITE 276 6.125 9104.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 15 MUD TYPE: LNS MUD DENSITY (LB/G): 13.10 MUD VISCOSITY (S) : 51.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 185.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 10.210 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1.410 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 91. 700 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 RE~zARKS: RAW MAIN PASS CASED HOLE DATA. USED PRIMARY DEPTH CONTROL. HEADING INFORMATION SUPPLIED BY CLIENT. $ LIS FORMAT DATA 65.0 65.0 65.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 16 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100665 O0 GRCH LDT GAPI 100665 O0 CALI LDT IN 100665 O0 TENS LDT LB 100665 O0 ENPH CNTG PU 100665 O0 ENRA CNTG 100665 O0 CFEC CNTG CPS 100665 O0 CNEC CNTG CPS 100665 O0 RCEF CNTG CPS 100665 O0 RCEN CNTG CPS 100665 O0 NPHI CNTG PU 100665 O0 TNPH CNTG PU 100665 O0 TNRA CNTG 100665 O0 RTNR CNTG 100665 O0 NPOR CNTG PU 100665 O0 RCNT CNTG CPS 100665 O0 RCFT CNTG CPS 100665 O0 CNTC CNTG CPS 100665 O0 CFTC CNTG CPS 100665 O0 MTE~I CNTG DEGF 100665 O0 MRES CNTG OHMM 100665 O0 HTEN CNTG LB 100665 O0 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9140.000 GRCH. LDT 69.688 CALI.LDT 6.527 TENS.LDT ENPH. CNTG 40.845 ENRA.CNTG 5.575 CFEC. CNTG 510.087 CNEC. CNTG RCEF. CNTG 547.332 RCEN. CNTG 2806.814 NPHI.CNTG 63.322 TNPH. CNTG TNRA.CNTG 4.464 RTNR.CNTG 4.900 NPOR.CNTG 53.777 RCNT. CNTG RCFT. CNTG 401.201 CNTC. CNTG 1707.391 CFTC. CNTG 404.941 MTEM. CNTG FiRES. CNTG 0.969 HTEN. CNTG 864.000 DEPT. 8975.000 GRCH. LDT 161.500 CALI.LDT 6.227 TENS.LDT ENPH. CNTG 41.888 ENRA. CNTG 5.655 CFEC. CNTG 488.002 CNEC. CNTG RCEF. CNTG 487.095 RCEN. CNTG 2357.456 NPHI.CNTG 52.462 TNPH. CNTG TNRA.CNTG 3.853 RTNR.CNTG 4.204 NPOR.CNTG 49.575 RCNT. CNTG RCFT. CNTG 505.376 CNTC. CNTG 1790.696 CFTC. CNTG 508.421 MTEM. CNTG MRES.CNTG 0.997 HTEN. CNTG 886.000 3975.000 2843.854 56.663 1894.909 134.825 3955.000 2759.526 44.790 1724.883 132.125 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 17 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CASED HOLE REPEAT PASSES Curves and log header data for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SU~24ARY VENDOR TOOL CODE START DEPTH LDT 9140.0 CNTG 9140.0 $ LOG HEADER DATA STOP DEPTH 8989.5 8989.5 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TCC TELEMETRY CARTRIDGE TCC TELEMETRY CARTRIDGE GR GAI4MA RAY CNTG COMPENSATED NEUTRON LDT LITHOLOGY DENSITY 16-JAN-97 CP 44.2 1100 17-JAN-97 1630 16-JAN-97 9715.0 9715.0 9140.0 9706.0 1800.0 TOOL NUMBER ........... TCM-AB 217 TCC SGC-SA CNC-GA 63 NSC-E 789 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 18 LDT LITHOLOGY DENSITY DITE PHASOR INDUCTION $ DRS-C 4824 DITE 276 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6. 125 9104.0 BOREHOLE CONDITIONS MUD TYPE: LNS MUD DENSITY (LB/G): 13.10 MUD VISCOSITY (S) : 51.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 185.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 10. 210 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 1. 410 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 91.700 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: RAW REPEAT CASED HOLE DATA. USED PRIMARY DEPTH CONTROL. HEADING INFORMATION SUPPLIED BY CLIENT. $ LIS FORMAT DATA 65.0 65.0 65.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 19 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100665 O0 000 O0 0 6 1 1 4 68 0000000000 GRCHLDT GAPI 100665 O0 000 O0 0 6 1 1 4 68 0000000000 CALI LDT IN 100665 O0 000 O0 0 6 1 1 4 68 0000000000 TENS LDT LB 100665 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH CNTG PU 100665 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA CNTG 100665 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI CNTG PU 100665 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH CNTG PU 100665 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA CNTG 100665 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR CNTG 100665 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR CNTG PU 100665 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC CNTG CPS 100665 O0 000 O0 0 6 1 1 4 68 0000000000 MTE~4 CNTG DEGF 100665 O0 000 O0 0 6 1 1 4 68 0000000000 MRES CNTG OFf,k4100665 O0 000 O0 0 6 1 1 4 68 0000000000 HTEN CNTG LB 100665 O0 000 O0 0 6 1 1 4 68 0000000000 * * DA TA * * DEPT. 9140. 000 GRCH.LDT 52. 594 CALI.LDT 6. 711 TENS.LDT ENPH. CNTG 48. 769 ENRA. CNTG 6. 242 CFEC. CNTG 430. 929 CNEC. CNTG RCEF. CNTG 421. 061 RCEN. CNTG 2696. 712 NPHI. CNTG 61. 097 TNPH. CNTG TNRA . CNTG 4 . 354 R TNR . CNTG 4.340 NPOR . CNTG 48.940 R CNT. CNTG RCFT. CNTG 409.319 CNTC. CNTG 1706.600 CFTC. CNTG 426.158 MTEM. CNTG MRES. CNTG O. 965 HTEN. CNTG 888. 000 4095.000 2689.679 52.212 1914.071 134.994 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JAN-1997 12:27 PAGE: 2O DEPT. 8993.500 GRCH. LDT 173. 000 CALI.LDT ENPH. CNTG 48.150 ENR~ . CNTG 6.176 CFEC . CNTG RCEF. CNTG 377. 887 RCEN. CNTG 2259. 988 NPHI. CNTG TNRA. CNTG 4.313 R TNR. CNTG 4 . 043 NPOR. CNTG RCFT. CNTG 336. 775 CNTC. CNTG 1597.142 CFTC. CNTG MRES. CNTG O. 999 HTEN. CNTG 870. 500 6.285 TENS.LDT 409. 326 CNEC. CNTG 60. 823 TNPH. CNTG 57. 572 RCNT. CNTG 384.104 MTEM. CNTG 4040.000 2527.896 55.483 1629.013 131.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE : 97/01/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/01/31 ORIGIN : FLIC TAPE NAME : 97037 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, 2F-18, KUPARUK, API #50-029-22720-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/01/31 ORIGIN : FLIC REEL NAME : 97037 CONTINUATION # : PREVIOUS REEL : CO~4~ENT : ARCO ALASKA INC, 2F-18, KUPARUK, API #50-029-22720-00