The URL can be used to link to this page

Home My WebLink About192-103 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 192-103/ 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: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 106' 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-40 117' 9-5/8" J-55 2749' 7" J-55 6319' 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 9375'3-1/2" Surface-2096' 18 bbls 15.8 ppg cement Surface-311' 6 bbls 15.7 ppg Class I/II Cement 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, TUBING RECORD 198 sx Class G8.5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 2/5/2024 192-103/ 323-293/ 323-688 50-103-20185-00-00 KRU 2M-01114' FSL, 19' FWL, Sec. 27, T11N, R8E, UM 1147' FSL, 1315' FEL, Sec. 29, T11N, R8E, UM ALK 2671 10/21/1992 Surface/ Surface 41' P.O. Box 100360, Anchorage, AK 99510-0360 487859 5948986 1099' FSL, 1096' FEL, Sec. 29, T11N, R8E, UM CASING WT. PER FT.GRADE 10/27/1992 CEMENTING RECORD 5949984 1400' MD/ 1392' TVD SETTING DEPTH TVD 5950029 TOP HOLE SIZE AMOUNT PULLED 481462 481248 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- Abandoned ADL0025585, ADL0025586 9800' MD/ 6331' TVD BOTTOM CASING, LINER AND CEMENTING RECORD SIZE DEPTH SET (MD) 9339' MD/ 5973' TVD PACKER SET (MD/TVD) 24" 12.25" 225 sx PermaFrost C Surface Surface 3346'Surface Surface If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# Surface 62.50# 36# 117' Surface 9785' 311-9345' (Tubing) Plugged and Abandoned 9435-9489' MD and 6044-6085' TVD (Cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. Sr Res EngSr Pet GeoSr Pet Eng 1819' MD/ 1782' TVD Oil-Bbl: Water-Bbl: 78.5 bbls 15.8 ppg cement 2096-9345' (IA) 191.5 bbls 15.8 ppg Cement to backside Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 564 sx PermaFrost E, 600 sx Class G Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 11:05 am, Feb 29, 2024 Abandoned 2/5/2024 JSB RBDMS JSB 030624 xGDSR-3/14/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1400' 1392' 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 Senior Well Intervention 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: Formation Name at TD: 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: 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. 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. 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). Authorized Name and N/A Plugged and Abandoned N/A Plugged and Abandoned 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. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov 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: 2024.02.28 15:31:10-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,375.0 2M-01 12/17/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: P&A Well - AOGCC WITNESS TOC & MARKER PLATE (COMPLETE - ADAM EARL) WELD MARKER PLATE 2M-01 2/13/2024 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: WELL SUSPENDED, PLANNED SIDETRACK/LATERAL NOT DONE 7/16/2012 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 50.0 117.0 117.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 50.0 3,344.5 2,748.4 36.00 J-55 BTC PRODUCTION 7 6.28 50.0 9,791.0 6,323.9 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 50.0 Set Depth … 9,375.2 Set Depth … 5,999.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 50.0 50.0 0.08 HANGER 8.000 FMC GEN IV TUBING HANGER- (removed was 3.08' now 0' length) 3.500 1,818.8 1,782.1 23.12 SAFETY VLV 5.250 CAMCO TRDP-4A SSSV CAMCO TRDP- 4A 2.812 3,449.8 2,803.4 58.73 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 6,839.4 4,514.6 60.62 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 8,545.0 5,414.9 50.94 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 9,119.1 5,810.5 42.70 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 9,286.2 5,933.7 42.62 GAS LIFT 5.968 CAMCO MMG-2 CAMCO MMG-2 2.920 9,338.4 5,972.1 42.72 SEAL ASSY 5.000 LOCATOR SEAL ASSY w/5' EXTRA SPACER TUBE OD 4.5", ID 2.985" BAKER GBH-22 4.000 9,339.2 5,972.7 42.72 PACKER 5.875 FB-1 PACKER w/CROSSOVER & SBE (OD 5.0", ID 4.0" SEAL BORE) BAKER FB-1 4.000 9,362.6 5,989.9 42.52 NIPPLE 4.520 CAMCO D NIPPLE NO GO CAMCO D 2.750 9,374.3 5,998.5 42.37 SOS 4.000 SHEAR OUT. TTL ELMD @ 9362' SWS LET 11/3/1992 BAKER 2.992 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) 50.0 50.0 0.08 MARKER PLATE AOGCC WITNESS TOC AND MARKER PLATE (COMPLETE - ADAM EARL) WELD MARKER PLATE TO THE WELL STUB (COMPLETE) REMOVE SHORING CAN (COMPLETE) BACKFILL EXCAVATION 2/3/2024 0.000 162.0 162.0 0.56 TUBING PUNCH PERFORATE 3.5" TUBING & 7" PC, 5FT, 2.5" HSD, 6 SPF, 60° PHASE 12/26/2023 2.992 295.0 295.0 0.68 TUBING PUNCH PERFORATE 3.5" TUBING & 7" PC, 2.5" HSD, 6 SPF, 60° PHASE 11/22/2023 2.992 297.0 297.0 0.69 TUBING PUNCH 3FT OF TUBING PUNCH, 4SPF, 0° PHASE, 12 HOLES TOTAL 11/6/2023 2.992 9,345.0 5,976.9 42.70 CMT SQZ CEMENT SQUEEZE w/ 17 PPG CLASS G CEMENT, PLACED APPROX 13 BBLS OF CEMENT BEHIND PIPE. TOC @ 9345'. 5/29/2012 0.000 9,357.0 5,985.8 42.58 TBG PUNCH PERF w/ 2" IS-HMX-BH, 6 SPF, 60 DEG PHASE 5/26/2012 2.992 9,407.0 6,022.8 41.74 FISH Mill, Motor, orienter output shaft, overshot and bait sub, 6/17/2012 0.000 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) 3,449.8 2,803.4 58.73 1 GAS LIFT DMY BK 1 0.0 5/21/2012 0.000 6,839.4 4,514.6 60.62 2 GAS LIFT DMY INT 1 0.0 5/21/2012 0.000 8,545.0 5,414.9 50.94 3 GAS LIFT DMY BTM 1 0.0 5/24/2012 0.000 9,119.1 5,810.5 42.70 4 GAS LIFT DMY BK 1 0.0 12/18/1992 0.000 9,286.2 5,933.7 42.62 5 GAS LIFT OPEN RK 1 1/2 12/17/2015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 162.0 167.0 162.0 167.0 12/26/2023 6.0 APERF PERFORATE 3½" TUBING & 7" PC, 2½" HSD, 60° PHASE 295.0 300.0 295.0 300.0 11/22/2023 6.0 APERF PERFORATE 3½" TUBING & 7" PC, 2½" HSD, 6 SPF, 60° PHASE 9,435.0 9,489.0 6,043.8 6,084.6 C-4, A-3, 2M-01 12/18/1992 4.0 IPERF 4½" Csg Gun, 180° phasing 2M-01, 2/28/2024 2:45:36 PM Vertical schematic (actual) PRODUCTION; 50.0-9,791.0 CMT SQZ; 9,345.0 IPERF; 9,435.0-9,489.0 FISH; 9,407.0 TBG PUNCH; 9,357.0 PACKER; 9,339.2 GAS LIFT; 9,286.2 GAS LIFT; 9,119.1 GAS LIFT; 8,545.0 GAS LIFT; 6,839.4 GAS LIFT; 3,449.8 SURFACE; 50.0-3,344.5 Cement Plug; 1,979.0 ftKB SAFETY VLV; 1,818.8 Cement Plug; 460.0 ftKB TUBING PUNCH; 297.0 TUBING PUNCH; 295.0 APERF; 295.0-300.0 Cement Plug; 174.0 ftKB APERF; 162.0-167.0 TUBING PUNCH; 162.0 CONDUCTOR; 50.0-117.0 Cement Plug; 84.0 ftKB Stage Cementing; 72.0 ftKB MARKER PLATE; 50.0 Cement Plug; 50.0 ftKB Cement Plug; 50.0 ftKB Cement Plug; 50.0 ftKB Squeeze – Behind Casing Squeeze; 50.0 ftKB KUP PROD KB-Grd (ft) 46.02 RR Date 10/30/199 2 Other Elev… 2M-01 ... TD Act Btm (ftKB) 9,800.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018500 Wellbore Status PROD Max Angle & MD Incl (°) 61.81 MD (ftKB) 2,801.74 WELLNAME WELLBORE2M-01 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 50.0 50.0 50.0 50.0 OA Top Off to Surface 50.0 117.0 50.0 117.0 Squeeze – Behind Casing Squeeze 225 sx PermaFrost C - CONDUCTOR 460.0 9,286.0 459.9 5,933.6 Cement Plug Plug #2- 270 bbl 15.8 ppg Class G Cement (T and IA) 11/2/2023 1,979.0 9,286.0 1,925.4 5,933.6 Cement Plug Plug #2 270 bbl 15.8 ppg Class G Cement (T, IA) 11/2/2023 72.0 300.0 72.0 300.0 Stage Cementing Plug # 3-15.8 PPG CEMENT AND PUMPED DOWN THE TUBING AND OUT THE O/A. A TOTAL OF 18 BBL'S OF CEMENT WAS PUMPED BEFORE CEMENT WAS SEEN ON SURFACE 11/25/2023 84.0 300.0 84.0 300.0 Cement Plug Plug #3 18 bbls 15.8 ppg Cement (T, IA, OA) 11/25/2023 174.0 300.0 174.0 300.0 Cement Plug Plug #3 18 bbls 15.8 ppg Cement (T, IA, OA) 11/25/2023 50.0 164.0 50.0 164.0 Cement Plug 15.8 ppg PermaFrost Cement 10 bbl OA, 10.8 bbl TxIA 1/1/2024 50.0 164.0 50.0 164.0 Cement Plug 15.8 ppg PermaFrost Cement 10 bbl OA, 10.8 bbl TxIA 1/1/2024 50.0 164.0 50.0 164.0 Cement Plug 15.8 ppg PermaFrost Cement 10 bbl OA, 10.8 bbl TxIA 1/1/2024 2M-01, 2/28/2024 2:45:37 PM Vertical schematic (actual) PRODUCTION; 50.0-9,791.0 CMT SQZ; 9,345.0 IPERF; 9,435.0-9,489.0 FISH; 9,407.0 TBG PUNCH; 9,357.0 PACKER; 9,339.2 GAS LIFT; 9,286.2 GAS LIFT; 9,119.1 GAS LIFT; 8,545.0 GAS LIFT; 6,839.4 GAS LIFT; 3,449.8 SURFACE; 50.0-3,344.5 Cement Plug; 1,979.0 ftKB SAFETY VLV; 1,818.8 Cement Plug; 460.0 ftKB TUBING PUNCH; 297.0 TUBING PUNCH; 295.0 APERF; 295.0-300.0 Cement Plug; 174.0 ftKB APERF; 162.0-167.0 TUBING PUNCH; 162.0 CONDUCTOR; 50.0-117.0 Cement Plug; 84.0 ftKB Stage Cementing; 72.0 ftKB MARKER PLATE; 50.0 Cement Plug; 50.0 ftKB Cement Plug; 50.0 ftKB Cement Plug; 50.0 ftKB Squeeze – Behind Casing Squeeze; 50.0 ftKB KUP PROD 2M-01 ... WELLNAME WELLBORE2M-01 2M-01 Current Condition COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 117 117 16 15.06 62.58 H-40 WELDED Surface 3344.00 2748 9.625 8.921 36 J-55 BTC Production/ Intermediate 9791.00 6324 7 6.276 26 J-55 BTC Tubing 9375.00 5999 3.5 2.992 9.3 J-55 AMB-EUE Surface Casing #1 Reservoir Suspension Plug TOC Tagged @ 9349' SLM Conductor Perfs 9435' - 9785' RKB Plug #2 TxIA TOC @ 460' RKB TOC IA @ 1979' RKB Bottom @ GLM 9286' RKB Plug #3 TOC OA 72' TOC IA 84' TOC tbg @ 174' Bottom @ ~300' RKB TOC OA calc'd 1553' RKB TOC 7" casing calc'd 7925' RKB Perforation @164' TOC tubing and IA @ surface OA TOC ~34' OA top job cement 34' to surface DTTMSTART JOBTYP SUMMARYOPS 6/29/2023 SUPPORT OTHER OPERATIONS pump 30bbls dsl down tbg up IA to verify circulation. job complete 10/30/2023 SUPPORT OTHER OPERATIONS HES SET CEMENT SILO. WELL SUPPORT BEGIN RUNNING HARDLINE AND SPOTTING TANKS WHEN POS BEGIN SETTING UP FOR UPCOMING P&A. 10/31/2023 SUPPORT OTHER OPERATIONS HES PRE-LOAD THEIR CEMENT SILO. WELL SUPPORT SET UP PIT LINER AND SPOT UPRIGHT AND RETU TANKS. 11/1/2023 SUPPORT OTHER OPERATIONS UPRIGHT TANKS WERE FILLED WITH 405 BBL'S OF BRINE. WELL SUPPORT COMPLETED THE R/U AND ALL HOSES AND HARDLINE. LRS PUMPERS CIRCULATED (T/IA) 390 BBL'S OF 80 DEG, 9.8 NACL BRINE. 11/2/2023 SUPPORT OTHER OPERATIONS CEMENTERS UNABLE TO PUMP ENTIRE CEMENT JOB DUE TO BLOCKAGE/LOCK UP TOWARDS END OF PROJECT. SUCCESSFULLY PUMPED THE FOLLOWING STAGES.10.2 BBL'S FRESH WATER SPACER, 270 15.8 CLASS G CEMENT, 3.4 BBL'S FRESH WATER SPACER. HES SHUT DOWN TO LINE UP/ PUMP DOWN WIPER BALL. WAS ONLY ABLE TO PUMP .5 BBL'S OF 9.8 BRINE (10 BBL'S SHY OF COMPLETING THE JOB WHEN THE WELL LOCKED UP. BYPASSED BALL LAUNCHER PUMPED DIRECTLY DOWN TUBING AGAIN, UNABLE TO PUMP. CALLED ENGINEER TO DISCUSS OPTIONS. PRESSURED UP TUBING TO 3000 PSI IN A ATTEMPT TO ESTABLISH RATE/CLEAR BLOCKAGE UNSUCCESSFULLY. SECURED WELL RDMO. ESTIMA TOC IS NOW ROUGHLY AROUND 460’ 11/2/2023 SUPPORT OTHER OPERATIONS CIR-OUT PUMPED 390 BBLS 9.8 BRINE DOWN TBG TAKING RETURN FROM IA JOB COMPLETE 11/3/2023 SUPPORT OTHER OPERATIONS UNABLE TO COMPLETE JOB DUE TO MALFUNCTIONING SSV...E-LINE TO RETURN AT A LATER DATE 11/4/2023 SUPPORT OTHER OPERATIONS UNABLE TO COMPLETE JOB DUE TO MALFUNCTIONING SSV. VALVE CREW UNABLE TO SHUT OR REPA LEAKING SSV. 11/6/2023 SUPPORT OTHER OPERATIONS TAG TOC @ 311.7' RKB, CONFER WITH TOWN ENGINEER, PUNCH 3FT OF HOLES IN 3.5" TUBING FROM 2 300.2' RKB, CCL TO TOP-SHOT = 5.5', CCL STOP 291.5' RKB, ATTEMPT TO CIRCULATE DOWN TUBING, PRESSURE UP, PUMP DOWN IA AND BREAK-DOWN ICE-PLUG, CIRCULATE 20 BBL DIESEL DOWN TUBIN UP IA. JOB COMPLETE. READY FOR PLAN FORWARD. 11/20/2023 SUPPORT OTHER OPERATIONS TAG TOC @ 311' RKB, LRS CONDUCTS PASSING CMIT AFTER MULTIPLE ATTEMTPS (AOGCC WITNESSE NOBLE). READY FOR E-LINE. 11/22/2023 SUPPORT OTHER OPERATIONS PERFORATE 3.5" & 7" PRODUCTION CASING FROM 295' TO 300' RKB, 5' HSD GUN, 6 SPF, & 60 DEGREE P CCL TO TOP-SHOT = 3.8', CCL STOP = 291.6'. ESTABLISHED CIRCULATION, PUMPED 30 BBLS OF DIESEL THROUGH TUBING TAKING RETURNS OFF IA AND OA AT 2 BBLS/MIN (~550 PSI). JOB IS READY FOR CEMENTING 11/25/2023 SUPPORT OTHER OPERATIONS PRIOR TO CEMENTING LRS PUMPERS/HES CEMENTERS CIRCULATE TO TANKS 85 BBL'S OF 80 DEG SEAWATER AND 20 BBL'S OF SURFACTANT WASH BETWEEN THE T/I/O. HES BATCHED UP 30 BBL'S OF PPG CEMENT AND PUMPED DOWN THE TUBING AND OUT THE O/A. A TOTAL OF 18 BBL'S OF CEMENT W PUMPED BEFORE CEMENT WAS SEEN ON SURFACE. THE O/A VALVE WAS THEN CLOSED. HES BEGAN PUMPING DOWN THE TUBING AND OUT OF THE I/A. A TOTAL OF 12 BBL'S OF CEMENT WAS PUMPED BE RUNNING OUT OF PRODUCT. NO T/IA CEMENT RETURNS WERE SEEN ON SURFACE. CALLED THE ENG AND DISCUSSED OPTIONS. IT WAS DECIDED TO EVACUATE ALL CEMENT IN THE TUBING AND I/A. CEME WAS CIRCULATED OUT OF THE T/IA AND FREEZE PROTECTED WITH 15 BBL'S OF DIESEL. THE CEMENT O/A WAS NOT CIRCULATED OUT, CURRENT CEMENT LEVEL IN THE O/A IS UNKNOWN. 11/28/2023 SUPPORT OTHER OPERATIONS (P & A) UNABLE TO ESTABLISH OA INJECTIVITY DUE TO BLOCKAGE IN HARDLINE. JOB IN PROGRESS U HARDLINE CAN BE REMOVED. 11/29/2023 SUPPORT OTHER OPERATIONS (P&A) T X IA CDDT PASSED TO 0 PSI, OA DDT PASSED TO 0 PSI, STRING LINED OA COMPANION SIDE TO AND OA CASING VALVE SIDE TO 100' WITHOUT TAGGING TOC OR FLUID. 11/30/2023 SUPPORT OTHER OPERATIONS (P & A) T FL AT SURFACE, STRING LINE SETS DOWN AT 195', IA FL AT SURFACE, STRING LINE SETS DO IC SPOOL. UNABLE TO ESTABLISH COMMUNICATION BETWEEN T, IA & OA UP TO 1000 PSI. T DDT (IN PROGRESS), IA DDT (IN PROGRESS), OA DDT (IN PROGRESS). 12/1/2023 SUPPORT OTHER OPERATIONS (P&A) T, IA, AND OA DDT PASSED TO 0 PSI. 12/15/2023 SUPPORT OTHER OPERATIONS TAG TOC @ 178' SLM. PRESSURE UP TBG TO 2000 PSI. OPEN BOTH IA & OA TO OPEN BLEED, LOST 50 TBG IN 15 MINUTES. NO FLOW OBSERVED FRON IA OR OA. RIG DOWN FOR PLAN FORWARD. 12/19/2023 SUPPORT OTHER OPERATIONS PERFORM CEMENT BOND LOG, LOG CORRELATED TO TUBING TALLY DATED 12/18/1992. TAGGED TD A 212.0'. PERFORM MAIN PASS FROM 212.0' TO SURFACE. TOP OF CEMENT FOUND AT 84.0' 2M-01 Plug and Abandon Summary of Operations 12/26/2023 SUPPORT OTHER OPERATIONS PERFORATE 5' X 2.5" HSD GUN OVER INTERVAL 162' - 167', CCL TO TOP-SHOT = 3', CCL STOP = 159' RKB CORRELATE TO AK ELINE CBL LOG DATED 19-DEC-2023. JOB IS READY FOR PUMPING 12/26/2023 SUPPORT OTHER OPERATIONS CIRCULATE FROM TUBING TO IA , RETURNS MATCH PUMP RATE UP TO 2BPM 1400 PSI AT PUMP 60 PSI LINED UP CIRCULATE FROM TUBING TO OA STARTED AT .6 BPM NO RETURNS OBSERVED, PUMP PRES 400 PSI OA CASING VALVE PSI 20, PUMPED 10 BBL. LINED UP TO PUMP THROUGH OA CASING VALVE TO ,PRESSURED UP TO 1500, LESS THAN .1 BBL MOVED, LINED UP TO PUMP DOWN IA TO TUBING, GOOD CIRCULATION UP TO 1.5BPM PUMP PRESSURE 1400 PSI, TUBING PSI 40. LINED UP TO PUMP DOWN OA TUBING, NO FLUID MOVED PRESSURED UP TO 1500 PSI. JOB IN PROGRESS 12/27/2023 SUPPORT OTHER OPERATIONS (P&A) OA DDT TO 0 PSI (PASSED), STRING LINE OA (SAT DOWN AT 33'). 12/31/2023 SUPPORT OTHER OPERATIONS CIRCULATION TEST, RIG UP ON THE IA TAKING RETURNS TO TUBING, HEAT FLUID TO 130 ° F PUMP 35 MAX PSI 1500, MAX RATE 2BPM, OA GAUGE INCREASED TO 200 PSI,TIED INTO THE OA PRESSURED UP 1000 PSI HELD FOR 15 MINUTES, NO SIGNIFICANT PRESSURE CHANGE BEYOND PUMP LEAK OFF. 1/1/2024 SUPPORT OTHER OPERATIONS CEMENT JOB, ALIGNED VALVES TO PUMP THROUGH TUBING TAKING RETURNS FROM THE IA , PUMPED BBL SEAWATER FOLLOWED BY A 10 BBL SURFACTANT WASH, CHASED WITH SEAWATER FLUSH, MIXE LB PERMAFROST CEMENT, PUMPED 10.8 BBL CEMENT BEFORE GETTING GOOD CEMENT RETURNS, MA 880, SHUT DOWN CLOSED THE IA BROUGHT RATE UP TO .4 BPM 440 PSI PUMPING INTO THE OA, NO PRESSURE WAS OBSERVED ON THE SURFACE GAUGE, AFTER 8 BBL DISPLACED BROUGHT RATE TO . 660 PSI FOR THE FINAL 2 BBL, A TOTAL OF 10 BBL PUMPED IN THE OA, TJV 20 BBL.15.8 PERMAFROST CEMENT. JOB COMPLETE 1/8/2024 ACQUIRE DATA (P&A) DDT Tx IA TO 0 PSI. (PASS), DDT OA (IN PROGRESS) 1/9/2024 ACQUIRE DATA (P&A) DDT Tx IA TO 0 PSI. (PASS), DDT OA (IN PROGRESS) 1/10/2024 ACQUIRE DATA (P&A) OA DDT TO 0 PSI IN PROGRESS, IA TOC @ CASING VAVLVE AND IA COMPANION VR PLUG. 1/11/2024 ACQUIRE DATA (P&A) OA DDT (IN PROGRESS). OBTAIN OA TOC (34' TO CEMENT, 34' FLUID) & T TOC (38" TO CEMENT, 7 & IA TOC (@ IA VALVE) 1/16/2024 ACQUIRE DATA (P&A) OA DDT TO 0 PSI IN PROGRESS. 1/20/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS- OA TOPPED OFF WITH 6 BBLS OF 15.7 PPG CLASS I/II CEMENT, UNTIL 15.7 PPG C RETURNS RECEIVED THRU COMPAANION NIPPLE.. NEXT STEP ; VERIFY OA TOC & CHECK FOR LELs, REMOVE WELLHEAD PLATFORM AND VALVES. 1/21/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS VERIFIED OA TOP OF CEMENT AT SURFACE. 4 GAS METER READINGS 0 PP 0 PPM CO2, 20.9% O2, 0% LEL. LUBRCATED STUD BOLTS FOR TREE/IA VALVE REMOVAL. NEXT STEP: REMOVE WELL HEAD PLATFORM, TREE AND IA VALVE. 1/22/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS- REMOVED IA VALVE, CEMENT @ SURFACE, INSTALLED BLIND FLANGE ON I REMOVED WELLHEAD WORK PLATFORM AND LADDER. REMOVED TREE, CEMENT @ SURFACE, INSTAL TAPPED BLIND. NEXT STEP ; WELLHOUSE REMOVAL, FINISH OBTAINING ACWR FOR EXCAVATION. 1/23/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS- WAIT ON WEATHER, POST PHASE 3 PAD CLEAN UP ASSIST WITH NES LOAD SUPPORT. 1/24/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS- WAIT ON WEATHER, POST PHASE 3 PAD CLEAN UP ASSIST WITH NES LOAD SUPPORT., UNABLE TO PULL WELLHOUSE 1,2, &27 DUE TO HIGH WINDS. 1/25/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS - WAIT ON WEATHER - UNABLE TO PULL WELLHOUSE 1, 2, & 27 DUE TO HIGH WIN 1/26/2024 SUPPORT OTHER OPERATIONS (P&A) WELLHEAD SURVEY (COMPLETE) CUT AND REMOVED 6' 2" OF WELL AND WELLHEAD (COMPLETE 1/27/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS WOW TO PULL WELL HOUSES. 1/28/2024 SUPPORT OTHER OPERATIONS (P&A) IN PROGRESS - WAITING ON COLD WEATHER TO PULL WELL HOUSES. 1/29/2024 SUPPORT OTHER OPERATIONS (P&A) REMOVE WELL HOUSES 1,2, & 27 (COMPLETE) EXCAVATION TO 14' (IN PROGRESS) 1/30/2024 SUPPORT OTHER OPERATIONS (P&A) REMOVE THE STANDING PLATE (COMPLETE) EXCAVATION (IN PROGRESS) 1/31/2024 SUPPORT OTHER OPERATIONS (P&A) DRIVE THE SHORING "CAN" (COMPLETE) EXCAVATION (IN PROGRESS ~11') 2/1/2024 SUPPORT OTHER OPERATIONS (P&A) EXACATION (IN PROGRESS) 2/2/2024 SUPPORT OTHER OPERATIONS (P&A) EXCAVATION (COMPLETE) CUT & REMOVE THE WELL STUB (COMPLETE ~11' BELOW GRADE / ~6' BELOW TUNDRA) 2/3/2024 SUPPORT OTHER OPERATIONS (P&A) AOGCC WITNESS TOC AND MARKER PLATE (COMPLETE - ADAM EARL) WELD MARKER PLATE TO WELL STUB (COMPLETE) REMOVE SHORING CAN (COMPLETE) BACKFILL EXCAVATION (IN PROGRESS) 2/4/2024 SUPPORT OTHER OPERATIONS (P&A) BACKFILL / LEVEL EXCAVATION (COMPLETE) DEMOB EQUIPMENT (IN PROGRESS) 2/5/2024 SUPPORT OTHER OPERATIONS (P&A) AOGCC - ADAM EARL - WAIVED THE FINAL SITE CLEARANCE (COMPLETE) DEMOB EQUIPMENT (COMPLETE) 2024-0203_Surface_Abandon_KRU_2M-01_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 02-07-2024 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector KRU 2M-01 CPAI PTD 1921030; Sundry 323-293 02-03-2024: I traveled out to KRU 2M-01 to witness the surface abandonment. All strings had set-up, hard cement. The well was cut-off at 6 feet below tundra grade. Marker plate had all the correct information welded on it. Brennen Green was the CPAI representative on the job. The crew was given the approval to weld on the plate and bury. Attachments: Photos (2)   2024-0203_Surface_Abandon_KRU_2M-01_ae Page 2 of 2 Surface Abandonment -KRU 2M-01 (PTD 1921030) Photos by AOGCC Inspector A. Earl 2/3/2024 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: ___________________ 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): 9800'9407' Casing Collapse Conductor Surface Intermediate Production 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 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 writte n 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): 9339' MD and 5973' TVD 1819' MD and 1782' TVD Perforation Depth TVD (ft): Tubing Size: J-55 9375' 1/2/2024 Packer: Baker FB-1 Packer SSSV: Camco TRDP-4A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025585, ADL0025586 192-103 P.O. Box 100360, Anchorage, AK 99510 50-103-20185-00-00 ConocoPhillips Alaska, Inc. KRU 2M-01 N/A (P&A)Kuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6331' 9345' 5977' 311', 2496', 9345' MD 117' 2748' 117' 3344' 6324'9791' 16" 9-5/8" 76' 3305' Perforation Depth MD (ft): 9435-9489' (cemented) 9752' 6044-6085' (cemented) 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 16. Verbal Approval: Date: GAS By Grace Christianson at 2:11 pm, Dec 28, 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: 2023.12.28 13:51:57-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 323-688 10-407 X VTL 12/29/2023 A.Dewhurst 29DEC23 X Suspension extension approved to 02/28/2024. VTL 12/29/2023 X X Suspension extension AOGCC inspection required after cutoff and BEFORE remedial cementing Well abandonment marker to meet requirements of 20 AAC 25.120 Photo document all steps of surface abandonment *&:JLC 12/29/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.02 10:09:51 -09'00'01/02/24 RBDMS JSB 010324 2M-01 Updated Procedure Katherine O’Connor (214) 684-7400 12/27/23 This procedure is for the nal surface plug of cement. The cement is in the tubing and IA at ~311’ KB. The state witnessed tag and test was executed on 11/20/21. Please bring out this procedure PLUS the approved sundry whenever execu,ng the work, but only work o/ of this procedure. The objec,ve of this procedure is to nish the surface abandonment of this well. Based on our current understanding of the well, the OA has a cement top of 72’ (based on echometer and ll up volume), the IA’s cement top is ~175’ for good cement with some stringers above (based of CBL, and the ability to circulate from tubing to IA up the perfora,ons at 164’). And there is a minor surface casing leak from the perfora,ons at 164’ KB. Plan forward is to circ in a tubing and IA plug, and plug o/ the surface casing leak, and then cut o/ wellhead and do a cement top job on the OA for the nal 70’ of cement. Doing the top job will prevent us from further damaging the surface casing with another perfora,on. The original suspension expires 12/31/2023, and Conoco requests a 60 day extension in order to be able to fully P&A the well. Recap of the aempt at surface plug: Before we rigged up on the well, the tubing and IA passed CMIT-TxIA to 1700 psi and drawdown tests to 0. Perforated at 300’ MD Got good circula3on through tbg, up IA, and up the OA to surface Pumped TBG to OA and got cement to surface Swapped TBG to IA and ran out of cement, went to displace cement out of the IA and got some cement to surface, then lost returns. Was s3ll able to pump down, but unable to surface anymore 7uid. Displaced all of the cement out of the tubing and IA with diesel Condi3on of the well currently: Tubing, IA, and OA pass drawdown tests to 0 psi Unable to circulate into the OA, unable to pump into the OA Based o9 of echometer reading and OA :ll up volume, cement top in OA is at ~72’ KB Able to circulate at 2bpm tubing to IA Perforated at 164’ KB, small surface casing leak, ~0.6 bpm Calcula3ons Tubing: 0.0087 bbls/> x 164 > = 1.4 bbls IA: 0.0264 bbls/> x 164 > = 4.3 bbls OA: 0.0297 bbls /> x 164 > = 4.9 bbls Eline/Pumping – Punch holes and establish circ for surface plug 1. RIH and perforate through tubing and produc3on casing @ 164’ KB 2. Establish circula3on down the tubing, taking returns up the IA and then returns up the OA. Max pressure 2000 psi. Note rates and pressures. a. From the CBL there is stringy cement in the IA above from ~84’ - 164’ KB. b. Please note volume pumped vs volume returned in each annulus. 3. Swap to pump down OA, taking returns up IA. And then take returns up tubing. Note rates and pressures. 4. CMIT-TxIAxOA to 1500 psi and get LLR if there is one 5. If ~2bpm pump rate at <1500 psi is not achievable, contact Katherine O’Connor Tubing and IA plug Pumpers/Cement 1. RU to pump down the tubing and take returns from the IA (7” x 3.5” annulus) 2. Pumping down the tubing taking returns up the IA pump the following: a. ±10 bbls warm seawater b. ±10 bbls surfactant wash c. ±10 bbls seawater 3. If clean returns are not seen at surface from IA pump addi3onal 7uid 4. Con3nue taking returns from the IA and pump the following schedule: a. ±5 bbl FW spacer b. ±75 bbls of permafrost cement (planned excess for plugging o9 SC leak) 5. Once good returns are seen out the IA at surface, con3nue pumping down tubing to squeeze surface casing leak 6. Mix on the 7y and pump excess cement as needed to get good returns across all annuli and tubing OA Plug Surface Work & Top Job – Excavate wellhead, cut o9 below grade, well plate, back:ll 1. DHD to perform drawdown test on tubing, IA and OA 2. Remove well house. 3. Bleed o9 T/I/O to ensure all pressure is bled o9 the system. 4. Remove produc3on tree in prepara3on for excava3on and casing cut. 5. If shallow thaw condi3ons are found, have shoring box installed during the excava3on ac3vity to prevent lose ground from falling into the excava3on. 6. Cut o9 wellhead and all casing strings at 4 feet below original ground level. 7. Perform top job on OA annulus. Will need at least 2 bbls of cement for the OA top job. Es,mated TOC in OA at 70’. 8. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 9. Send the casing head with stub to materials shop. Photo document. 10. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following informa3on bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips KRU 2M-01 PTD #: 192-103 API #: 50-103-20185-00-00 11. Remove cellar. Back :ll cellar with gravel/:ll as needed. Back :ll remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. Report the :nal P&A has been completed to the AOGCC. Photo document :nal loca3on condi3on a>er work is completed cemen3ng unit and associated equipment. 1 Conklin, Amy A From:O'Connor, Katherine Sent:Wednesday, December 27, 2023 10:01 AM To:Conklin, Amy A Subject:FW: [EXTERNAL]Re: 2M-01 (PTD:192-103) P&A Update APPROVAL From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 22, 2023 7:58 AM To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: [EXTERNAL]Re: 2M-01 (PTD:192-103) P&A Update APPROVAL 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 to proceed as planned below. An extension of the suspension is granted to 1/31/24. Please submit a 10-403 change of approved program asap outlining this work and the extension request. Victoria Sent from my iPhone On Dec 20, 2023, at 12:02CPM, O'Connor, Katherine <Katherine.OConnor@conocophillips.com > wrote: Hi Victoria A recap of 2M-01 and the tentative plan forward if you approve. I have attached the current schematic, proposed P&A schematic, the CBL we ran yesterday. Condition of the well currently: 1. Tubing, IA, and OA pass drawdown tests to 0 psi 2. Stringlined OA to 400’ MD, did not tag up on any cement 3. Unable to circulate into the OA (it pressures up) 4. Unable to circulate tubing to IA or OA (max pressure has been 2000 psi, pressures up) 5. TOC in IA at 84’ KB 6. TOC in tubing at 174’ KB Plan forward: 1. Perforate tubing – IA – OA at 164’ KB 2. Attempt to get circulation through all strings, tubing -> IA, tubing -> OA, IA -> OA 1. Monitor returns to see if on any losses & note 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. Circulate IA to tubing, and OA to tubing as well 3. If able to circulate tubing -> IA and OA 1. Proceed with abandonment from 164’ to surface, pumping cement in tubing to OA, then tubing to IA, leaving cement in all strings to surface 4. If unable to circulate tubing to IA BUT can circulate tubing to OA 1. Circulate cement from tubing to OA 2. Cement OA to surface 3. Displace all cement out of tubing (want to give space in case OA cement inflows, do not want to punch any shallower in the next step) 1. Ensure to leave pressure on tubing to keep OA cement in place 4. Punch tubing @ ~75’ KB, confirm circulation tubing to IA 5. Cement IA and tubing to surface 5. If unable to get any circulation 1. Discuss path forward, possible top job with stinger in all three strings And will email approval suffice for an extension or do we need a suspension extension on the one we already have? Thank you Katherine Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From: O'Connor, Katherine Sent: Thursday, December 14, 2023 8:35 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: 2M-01 (PTD:192-103) P&A Update Hi Victoria I wanted to give a revision to the email below. As we’ve continued to diagnose and evaluate the condition of the well, I don’t believe milling out cement is necessary. We can achieve the plan outlined originally to pump a shallow cement plug to surface. The plan forward will be to tag cement in the tubing, attempt circulation TxIA and then TxOA (max pressure 2000 psi). Then run a CBL to see if there is cement in the IA, and if so where. Ultimate goal is to reattempt a surface plug and get >150’ of cement into the tubing, IA, and OA per the regulation. Recap of the attempt at surface plug: 1. Before we rigged up on the well, the tubing and IA passed CMIT-TxIA to 1700 psi and drawdown tests to 0. 2. Perforated at 300’ MD 3. Got good circulation through tbg, up IA, and up the OA to surface 4. Pumped TBG to OA and got cement to surface 5. Swapped TBG to IA and ran out of cement, went to displace cement out of the IA and got some cement to surface, then lost returns. Was still able to pump down, but unable to surface anymore fluid. 3 6. Displaced all of the cement out of the tubing and IA with diesel 7. RDMO Condition of the well currently: 7. Tubing, IA, and OA pass drawdown tests to 0 psi 8. Stringlined OA to 400’ MD, did not tag up on any cement 9. Unable to circulate into the OA (it pressures up) 10. Unable to circulate tubing to IA or OA (max pressure has been 800 psi, pressures up) My goal is to just concentrate on the surface plug and getting cement to surface. The well is in good condition; it has passing pressure tests and passes drawdown tests to 0 psi. I believe the lack of circulation is from the OA cement slumping back into the perfs. Running a CBL and getting circulation will inform at what depth we can pump the surface plug. I will keep you informed of what we discover before pumping any sort of surface cement. Also, given the many challenges on this well I do not believe we will be able to get the surface excavation done before the end of 2023. What do I need for an extension given the suspension expires Dec 31, 2023? Thank you Katherine O’Connor Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, December 11, 2023 8:19 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: O'Connor, Katherine <Katherine.OConnor@conocophillips.com >; Eschete, Allen <Allen.Eschete@conocophillips.com> Subject: RE: 2M-01 (PTD:192-103) P&A Update Good Morning Victoria, Allen reached out to me on this well prior to our meeting and I meant to add it to our agenda and failed. Can you provide direction on whether the work scope outlined by Allen can be handled under the original 403 or if a close out of the original is needed followed by a new 403. Thank-you! Greg From: Eschete, Allen <Allen.Eschete@conocophillips.com> Sent: Tuesday, December 5, 2023 4:36 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: O'Connor, Katherine <Katherine.OConnor@conocophillips.com >; Hobbs, Greg S 4 <Greg.S.Hobbs@conocophillips.com> Subject: RE: 2M-01 (PTD:192-103) P&A Update Victoria, I wanted to give you an update on this well and what our proposed path forward is. We performed additional testing and were unable to establish a circulation path between the tubing, IA, and OA and are also unable to pass an MIT in any of them as well but they all passed DDT as noted in the email below. We would like to go in with coil and mill the cement out of the tubing possibly as deep as 2600’ RKB and then run a CBL to see any cement from this most recent surface plug. This will inform us on where we will be able to punch holes to circulate cement and retry the surface abandonment. I know the surface plug required a 10-403 and 10-404 so I was also curious if we could continue this work under the original 10-403 or if you wanted us to close it out with a 10-404 and resubmit a 10-403. If you could review this and let me know if this is acceptable I would appreciate it. If you have any questions please feel free to call or email me. Thanks, Allen Eschete Office: (907) 265-6558 Cell: (661) 348-2949 From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com > Sent: Thursday, November 30, 2023 3:01 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Eschete, Allen <Allen.Eschete@conocophillips.com> Subject: 2M-01 (PTD:192-103) P&A Update Hi Victoria An update on 2M-01. E-line perforated at 300’ MD, and confirmed circulation from TBG x IA x OA, they saw returns to surface from both the IA and the OA. When cementers went out this past weekend they got cement to surface in the OA, but were not able to get cement to surface in the IA. They pumped 50% excess, so should have easily gotten cement to surface in both the OA and the IA. Since they didn’t see surface returns up the IA, they circulated TBG x IA out with diesel that way we didn’t end up with an unknown TOC in the IA. Intent was to leave the TBG and IA clean, and allow the OA cement to set up. We have been out there this week trying to determine what condition the well is in. Currently there is no cement in the OA (they dropped a string line down the OA to determine TOC and made it down to 400’ without tagging up). The tubing, IA, and OA pass drawdown tests to 0 psi. We suspect a surface casing leak, likely from the punch. Plan forward is to confirm circulation paths. Unless we discover a change in our ability to circulate, the plan will be to go back out there with a larger volume of cement, lighter permafrost cement (to minimize the risk of the cement swapping out with any fluid below), and cement with an accelerant so it sets up faster. Just wanted to update you. I will be out of office 12/1 – 12/10 with no cell coverage and minimal WiFi. Allen Eschete will be covering (cell: 661-348-2949). Thanks! 5 Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) <2M-01 P&A Schematic 12-20-23.xlsm> <4629_CPAI_2M-01_CBL_19Dec23_FieldPrint.pdf> <2M-01 P&A Schematic FINAL 12-20-23.xlsm> Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,375.0 2M-01 12/17/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added 5' of perforations through 3.5" tubing & 7" PC (162' - 167' RKB) 2M-01 12/26/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: WELL SUSPENDED, PLANNED SIDETRACK/LATERAL NOT DONE 7/16/2012 osborl NOTE: View Schematic w/ Alaska Schematic9.0 3/8/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 117.0 117.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 39.2 3,344.5 2,748.4 36.00 J-55 BTC PRODUCTION 7 6.28 39.2 9,791.0 6,323.9 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 37.6 Set Depth … 9,375.2 Set Depth … 5,999.2 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.6 37.6 0.03 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,818.8 1,782.1 23.12 SAFETY VLV 5.250 CAMCO TRDP-4A SSSV CAMCO TRDP- 4A 2.812 3,449.8 2,803.4 58.73 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 6,839.4 4,514.6 60.62 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 8,545.0 5,414.9 50.94 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 9,119.1 5,810.5 42.70 GAS LIFT 5.312 CAMCO FMHO CAMCO FMHO 2.867 9,286.2 5,933.7 42.62 GAS LIFT 5.968 CAMCO MMG-2 CAMCO MMG-2 2.920 9,338.4 5,972.1 42.72 SEAL ASSY 5.000 BAKER GBH-22 LOCATOR SEAL ASSY w/5' EXTRA SPACER TUBE OD 4.5", ID 2.985" BAKER GBH-22 4.000 9,339.2 5,972.7 42.72 PACKER 5.875 BAKER FB-1 PACKER w/CROSSOVER & SBE (OD 5.0", ID 4.0" SEAL BORE) BAKER FB-1 4.000 9,362.6 5,989.9 42.52 NIPPLE 4.520 CAMCO D NIPPLE NO GO CAMCO D 2.750 9,374.3 5,998.5 42.37 SOS 4.000 BAKER SHEAR OUT. TTL ELMD @ 9362' SWS LET 11/3/1992 BAKER 2.992 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) 162.0 162.0 0.56 TUBING PUNCH PERFORATE 3.5" TUBING & 7" PC, 5FT, 2.5" HSD, 6 SPF, 60 DEGREE PHASE 12/26/2023 2.992 295.0 295.0 0.68 TUBING PUNCH PERFORATE 3.5" TUBING & 7" PC, 2.5" HSD, 6 SPF, 60 DEGREE PHASE 11/22/2023 2.992 297.0 297.0 0.69 TUBING PUNCH 3FT OF TUBING PUNCH, 4SPF, 0 DEGREE PHASE, 12 HOLES TOTAL 11/6/2023 2.992 9,345.0 5,976.9 42.70 CMT SQZ CEMENT SQUEEZE w/ 17 PPG CLASS G CEMENT, PLACED APPROX 13 BBLS OF CEMENT BEHIND PIPE. TOC @ 9345'. 5/29/2012 0.000 9,357.0 5,985.8 42.58 TBG PUNCH PERF w/ 2" IS-HMX-BH, 6 SPF, 60 DEG PHASE 5/26/2012 2.992 9,407.0 6,022.8 41.74 FISH Mill, Motor, orienter output shaft, overshot and bait sub, 6/17/2012 0.000 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) 3,449.8 2,803.4 58.73 1 GAS LIFT DMY BK 1 0.0 5/21/2012 0.000 6,839.4 4,514.6 60.62 2 GAS LIFT DMY INT 1 0.0 5/21/2012 0.000 8,545.0 5,414.9 50.94 3 GAS LIFT DMY BTM 1 0.0 5/24/2012 0.000 9,119.1 5,810.5 42.70 4 GAS LIFT DMY BK 1 0.0 12/18/1992 0.000 9,286.2 5,933.7 42.62 5 GAS LIFT OPEN RK 1 1/2 12/17/2015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 162.0 167.0 162.0 167.0 12/26/2023 6.0 APERF PERFORATE 3.5" TUBING & 7" PC, 2.5" HSD, 6 SPF, 60 DEGREE PHASE 295.0 300.0 295.0 300.0 11/22/2023 6.0 APERF PERFORATE 3.5" TUBING & 7" PC, 2.5" HSD, 6 SPF, 60 DEGREE PHASE 9,435.0 9,489.0 6,043.8 6,084.6 C-4, A-3, 2M-01 12/18/1992 4.0 IPERF 4 1/2" Csg Gun, 180 deg. phasing Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 2,096.0 9,345.0 2,024.0 5,976.9 Primary – Full Bore PUMPED 15.8 # CEMENT, 191.5' BBL TO BACKSIDE 11/2/2023 9,345.0 9,785.0 5,976.9 6,319.1 CEMENT 5/30/2012 311.0 9,345.0 311.0 5,976.9 Cement Plug PUMPED 15.8 # CEMENT,78.5' BBL TO TUBING 11/2/2023 2M-01, 12/27/2023 10:30:59 AM Vertical schematic (actual) PRODUCTION; 39.2-9,791.0 CMT SQZ; 9,345.0 IPERF; 9,435.0-9,489.0 FISH; 9,407.0 TBG PUNCH; 9,357.0 PACKER; 9,339.2 CEMENT; 9,345.0 ftKB GAS LIFT; 9,286.2 GAS LIFT; 9,119.1 GAS LIFT; 8,545.0 GAS LIFT; 6,839.4 GAS LIFT; 3,449.8 SURFACE; 39.2-3,344.5 Primary – Full Bore; 2,096.0 ftKB SAFETY VLV; 1,818.8 Cement Plug; 311.0 ftKB TUBING PUNCH; 297.0 TUBING PUNCH; 295.0 APERF; 295.0-300.0 TUBING PUNCH; 162.0 APERF; 162.0-167.0 CONDUCTOR; 41.0-117.0 KUP PROD KB-Grd (ft) 46.02 RR Date 10/30/199 2 Other Elev… 2M-01 ... TD Act Btm (ftKB) 9,800.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032018500 Wellbore Status PROD Max Angle & MD Incl (°) 61.81 MD (ftKB) 2,801.74 WELLNAME WELLBORE2M-01 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP From:O"Connor, Katherine To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]Re: 2M-01 (PTD:192-103) P&A Update APPROVAL Date:Thursday, December 28, 2023 12:59:50 PM Attachments:2M-01 Updated Procedure - Final Surface Plug Sundry 12-27-23.docx Hi Victoria The saga of 2M-01 continues… they perforated at 164’ over Christmas and were able to get circulation from tubing to IA, but unable to get circulation into the OA. Also unable to pump down the OA. This means there is good cement in the OA above the perf at 164’. We previously did not think there was cement there because DHD stringlined to 400’, but they must have hit cement and did not realize it. Based off of a new stringline, and an echometer shot, suspected cement top in the OA is 33-70’ MD. I have updated the schematic to reflect this. Plan forward, upon approval, will be to circulate cement tubing to IA to surface, perform drawdown tests to 0, and then do a top job to get cement to surface in the OA. I have attached the procedure here, and today will be sending out the change of approved sundry (with this exact procedure). We have a cement crew available to do this on January 2nd, so seeking approval to continue forward through email. Thank you! Katherine O’Connor Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 22, 2023 9:13 AM To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: Re: [EXTERNAL]Re: 2M-01 (PTD:192-103) P&A Update APPROVAL Yes Sent from my iPhone On Dec 22, 2023, at 8:12ථAM, O'Connor, Katherine <Katherine.OConnor@conocophillips.com> wrote: 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. Hi Victoria Just to clarify, are we ok with moving forward with the work outlined below this weekend just based off of this email approval? I will work on getting a 403 change of approved program submitted. Thank you! Katherine From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 22, 2023 7:58 AM To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: [EXTERNAL]Re: 2M-01 (PTD:192-103) P&A Update APPROVAL 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 to proceed as planned below. An extension of the suspension is granted to 1/31/24. Please submit a 10-403 change of approved program asap outlining this work and the extension request. Victoria Sent from my iPhone On Dec 20, 2023, at 12:02ථPM, O'Connor, Katherine <Katherine.OConnor@conocophillips.com> wrote: Hi Victoria A recap of 2M-01 and the tentative plan forward if you approve. I have attached the current schematic, proposed P&A schematic, the CBL we ran yesterday. Condition of the well currently: 1. Tubing, IA, and OA pass drawdown tests to 0 psi 2. Stringlined OA to 400’ MD, did not tag up on any cement 3. Unable to circulate into the OA (it pressures up) 4. Unable to circulate tubing to IA or OA (max pressure has been 2000 psi, pressures up) 5. TOC in IA at 84’ KB 6. TOC in tubing at 174’ KB Plan forward: 1. Perforate tubing – IA – OA at 164’ KB 2. Attempt to get circulation through all strings, tubing -> IA, tubing -> OA, IA -> OA 1. Monitor returns to see if on any losses & note 2. Circulate IA to tubing, and OA to tubing as well 3. If able to circulate tubing -> IA and OA 1. Proceed with abandonment from 164’ to surface, pumping cement in tubing to OA, then tubing to IA, leaving cement in all strings to surface 4. If unable to circulate tubing to IA BUT can circulate tubing to OA 1. Circulate cement from tubing to OA 2. Cement OA to surface 3. Displace all cement out of tubing (want to give space in case OA cement inflows, do not want to punch any shallower in the next step) 1. Ensure to leave pressure on tubing to keep OA cement in place 4. Punch tubing @ ~75’ KB, confirm circulation tubing to IA 5. Cement IA and tubing to surface 5. If unable to get any circulation 1. Discuss path forward, possible top job with stinger in all three strings And will email approval suffice for an extension or do we need a suspension extension on the one we already have? Thank you Katherine Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From: O'Connor, Katherine Sent: Thursday, December 14, 2023 8:35 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: 2M-01 (PTD:192-103) P&A Update Hi Victoria I wanted to give a revision to the email below. As we’ve continued to diagnose and evaluate the condition of the well, I don’t believe milling out cement is necessary. We can achieve the plan outlined originally to pump a shallow cement plug to surface. The plan forward will be to tag cement in the tubing, attempt circulation TxIA and then TxOA (max pressure 2000 psi). Then run a CBL to see if there is cement in the IA, and if so where. Ultimate goal is to reattempt a surface plug and get >150’ of cement into the tubing, IA, and OA per the regulation. Recap of the attempt at surface plug: 1. Before we rigged up on the well, the tubing and IA passed CMIT- TxIA to 1700 psi and drawdown tests to 0. 2. Perforated at 300’ MD 3. Got good circulation through tbg, up IA, and up the OA to surface 4. Pumped TBG to OA and got cement to surface 5. Swapped TBG to IA and ran out of cement, went to displace cement out of the IA and got some cement to surface, then lost returns. Was still able to pump down, but unable to surface anymore fluid. 6. Displaced all of the cement out of the tubing and IA with diesel 7. RDMO Condition of the well currently: 7. Tubing, IA, and OA pass drawdown tests to 0 psi 8. Stringlined OA to 400’ MD, did not tag up on any cement 9. Unable to circulate into the OA (it pressures up) 10. Unable to circulate tubing to IA or OA (max pressure has been 800 psi, pressures up) My goal is to just concentrate on the surface plug and getting cement to surface. The well is in good condition; it has passing pressure tests and passes drawdown tests to 0 psi. I believe the lack of circulation is from the OA cement slumping back into the perfs. Running a CBL and getting circulation will inform at what depth we can pump the surface plug. I will keep you informed of what we discover before pumping any sort of surface cement. Also, given the many challenges on this well I do not believe we will be able to get the surface excavation done before the end of 2023. What do I need for an extension given the suspension expires Dec 31, 2023? Thank you Katherine O’Connor Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Monday, December 11, 2023 8:19 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; Eschete, Allen <Allen.Eschete@conocophillips.com> Subject: RE: 2M-01 (PTD:192-103) P&A Update Good Morning Victoria, Allen reached out to me on this well prior to our meeting and I meant to add it to our agenda and failed. Can you provide direction on whether the work scope outlined by Allen can be handled under the original 403 or if a close out of the original is needed followed by a new 403. Thank-you! Greg From: Eschete, Allen <Allen.Eschete@conocophillips.com> Sent: Tuesday, December 5, 2023 4:36 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: O'Connor, Katherine <Katherine.OConnor@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: 2M-01 (PTD:192-103) P&A Update Victoria, I wanted to give you an update on this well and what our proposed path forward is. We performed additional testing and were unable to establish a circulation path between the tubing, IA, and OA and are also unable to pass an MIT in any of them as well but they all passed DDT as noted in the email below. We would like to go in with coil and mill the cement out of the tubing possibly as deep as 2600’ RKB and then run a CBL to see any cement from this most recent surface plug. This will inform us on where we will be able to punch holes to circulate cement and retry the surface abandonment. I know the surface plug required a 10-403 and 10-404 so I was also curious if we could continue this work under the original 10-403 or if you wanted us to close it out with a 10-404 and resubmit a 10-403. If you could review this and let me know if this is acceptable I would appreciate it. If you have any questions please feel free to call or email me. Thanks, Allen Eschete Office: (907) 265-6558 Cell: (661) 348-2949 From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Sent: Thursday, November 30, 2023 3:01 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Eschete, Allen <Allen.Eschete@conocophillips.com> Subject: 2M-01 (PTD:192-103) P&A Update Hi Victoria An update on 2M-01. E-line perforated at 300’ MD, and confirmed circulation from TBG x IA x OA, they saw returns to surface from both the IA and the OA. When cementers went out this past weekend they got cement to surface in the OA, but were not able to get cement to surface in the IA. They pumped 50% excess, so should have easily gotten cement to surface in both the OA and the IA. Since they didn’t see surface returns up the IA, they circulated TBG x IA out with diesel that way we didn’t end up with an unknown TOC in the IA. Intent was to leave the TBG and IA clean, and allow the OA cement to set up. We have been out there this week trying to determine what condition the well is in. Currently there is no cement in the OA (they dropped a string line down the OA to determine TOC and made it down to 400’ without tagging up). The tubing, IA, and OA pass drawdown tests to 0 psi. We suspect a surface casing leak, likely from the punch. Plan forward is to confirm circulation paths. Unless we discover a change in our ability to circulate, the plan will be to go back out there with a larger volume of cement, lighter permafrost cement (to minimize the risk of the cement swapping out with any fluid below), and cement with an accelerant so it sets up faster. Just wanted to update you. I will be out of office 12/1 – 12/10 with no cell coverage and minimal WiFi. Allen Eschete will be covering (cell: 661-348- 2949). Thanks! Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) <2M-01 P&A Schematic 12-20-23.xlsm> <4629_CPAI_2M-01_CBL_19Dec23_FieldPrint.pdf> <2M-01 P&A Schematic FINAL 12-20-23.xlsm> 2M-01 Updated Procedure Katherine O’Connor (214) 684-7400 12/27/23 dŚŝƐƉƌŽĐĞĚƵƌĞŝƐĨŽƌƚŚĞĮŶĂůƐƵƌĨĂĐĞƉůƵŐŽĨĐĞŵĞŶƚ͘dŚĞĐĞŵĞŶƚŝƐŝŶƚŚĞƚƵďŝŶŐĂŶĚ/ĂƚΕϯϭϭ͛<͘ dŚĞƐƚĂƚĞǁŝƚŶĞƐƐĞĚƚĂŐĂŶĚƚĞƐƚǁĂƐĞǆĞĐƵƚĞĚŽŶϭϭͬϮϬͬϮϭ͘ WůĞĂƐĞďƌŝŶŐŽƵƚƚŚŝƐƉƌŽĐĞĚƵƌĞW>h^ƚŚĞ ĂƉƉƌŽǀĞĚƐƵŶĚƌǇǁŚĞŶĞǀĞƌĞǆĞĐƵƟŶŐƚŚĞǁŽƌŬ͕ďƵƚŽŶůǇǁŽƌŬŽīŽĨƚŚŝƐƉƌŽĐĞĚƵƌĞ͘ dŚĞŽďũĞĐƟǀĞŽĨƚŚŝƐƉƌŽĐĞĚƵƌĞŝƐƚŽĮŶŝƐŚƚŚĞƐƵƌĨĂĐĞĂďĂŶĚŽŶŵĞŶƚŽĨƚŚŝƐǁĞůů͘ĂƐĞĚŽŶŽƵƌĐƵƌƌĞŶƚ ƵŶĚĞƌƐƚĂŶĚŝŶŐŽĨƚŚĞǁĞůů͕ƚŚĞKŚĂƐĂĐĞŵĞŶƚƚŽƉŽĨϳϮ͛;ďĂƐĞĚŽŶĞĐŚŽŵĞƚĞƌĂŶĚĮůůƵƉǀŽůƵŵĞͿ͕ ƚŚĞ/͛ƐĐĞŵĞŶƚƚŽƉŝƐΕϭϳϱ͛ĨŽƌŐŽŽĚĐĞŵĞŶƚǁŝƚŚƐŽŵĞƐƚƌŝŶŐĞƌƐĂďŽǀĞ;ďĂƐĞĚŽĨ>͕ĂŶĚƚŚĞĂďŝůŝƚǇ ƚŽĐŝƌĐƵůĂƚĞĨƌŽŵƚƵďŝŶŐƚŽ/ƵƉƚŚĞƉĞƌĨŽƌĂƟŽŶƐĂƚϭϲϰ͛Ϳ͘ŶĚƚŚĞƌĞŝƐĂŵŝŶŽƌƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ ĨƌŽŵƚŚĞƉĞƌĨŽƌĂƟŽŶƐĂƚϭϲϰ͛<͘WůĂŶĨŽƌǁĂƌĚŝƐƚŽĐŝƌĐŝŶĂƚƵďŝŶŐĂŶĚ/ƉůƵŐ͕ĂŶĚƉůƵŐŽīƚŚĞ surfaĐĞĐĂƐŝŶŐůĞĂŬ͕ĂŶĚƚŚĞŶĐƵƚŽīǁĞůůŚĞĂĚĂŶĚĚŽĂĐĞŵĞŶƚƚŽƉũŽďŽŶƚŚĞKĨŽƌƚŚĞĮŶĂůϳϬ͛ŽĨ ĐĞŵĞŶƚ͘ŽŝŶŐƚŚĞƚŽƉũŽďǁŝůůƉƌĞǀĞŶƚƵƐĨƌŽŵĨƵƌƚŚĞƌĚĂŵĂŐŝŶŐƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐǁŝƚŚĂŶother ƉĞƌĨŽƌĂƟŽŶ͘ dŚĞŽƌŝŐŝŶĂůƐƵƐƉĞŶƐŝŽŶĞǆƉŝƌĞƐϭϮͬϯϭͬϮϬϮϯ͕ĂŶĚŽŶŽĐŽƌĞƋƵĞƐƚƐĂϲϬĚĂǇĞǆƚĞŶƐŝŽŶŝŶŽƌĚĞƌƚŽďĞ ĂďůĞƚŽĨƵůůǇWΘƚŚĞǁĞůů͘ ZĞĐĂƉŽĨƚŚĞĂƩĞŵƉƚĂƚƐƵƌĨĂĐĞƉůƵŐ͗ x Before we ƌŝŐŐĞĚƵƉŽŶƚŚĞǁĞůů͕ƚŚĞƚƵďŝŶŐĂŶĚ/ƉĂƐƐĞĚD/d-dǆ/ƚŽϭϳϬϬƉƐŝĂŶĚĚƌĂǁĚŽǁŶ ƚĞƐƚƐƚŽϬ͘ x WĞƌĨŽƌĂƚĞĚĂƚϯϬϬ͛D x 'ŽƚŐŽŽĚĐŝƌĐƵůĂƟŽŶƚŚƌŽƵŐŚƚďŐ͕ƵƉ/͕ĂŶĚƵƉƚŚĞKƚŽƐƵƌĨĂĐĞ x WƵŵƉĞĚd'ƚŽKĂŶĚŐŽƚĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ x ^ǁĂƉƉĞĚd'ƚŽ/ĂŶĚƌĂŶŽƵƚŽĨĐĞŵĞŶƚ͕ǁĞŶƚƚŽĚŝƐƉůĂĐĞĐĞŵĞŶƚŽƵƚŽĨƚŚĞ/ĂŶĚŐŽƚƐŽŵĞ ĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͕ƚŚĞŶůŽƐƚƌĞƚƵƌŶƐ͘tĂƐƐƟůůĂďůĞƚŽƉƵŵƉĚŽǁŶ͕ďƵƚƵŶĂďůĞƚŽƐƵƌĨĂĐĞ ĂŶǇŵŽƌĞŇƵŝĚ͘ x ŝƐƉůĂĐĞĚĂůůŽĨƚŚĞĐĞŵĞŶƚŽƵƚŽĨƚŚĞƚƵďŝŶŐĂŶĚ/ǁŝƚŚĚŝĞƐĞů ŽŶĚŝƟŽŶŽĨƚŚĞǁĞůůĐƵƌƌĞŶƚůǇ͗ x dƵďŝŶŐ͕/͕ĂŶĚKƉĂƐƐĚƌĂǁĚŽǁŶƚĞƐƚƐƚŽϬƉƐŝ x hŶĂďůĞƚŽĐŝƌĐƵůĂƚĞŝŶƚŽƚŚĞK͕ƵŶĂďůĞƚŽƉƵŵƉŝŶƚŽƚŚĞK x ĂƐĞĚŽīŽĨĞĐŚŽŵĞƚĞƌƌĞĂĚŝŶŐĂŶĚKĮůůƵƉǀŽůƵŵĞ͕ĐĞŵĞŶƚƚŽƉŝŶKŝƐĂƚΕϳϮ͛< x ďůĞƚŽĐŝƌĐƵůĂƚĞĂƚϮďƉŵƚƵďŝŶŐƚŽ/ x WĞƌĨŽƌĂƚĞĚĂƚϭϲϰ͛<͕ƐŵĂůůƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ͕ΕϬ͘ϲďƉŵ ĂůĐƵůĂƟŽŶƐ dƵďŝŶŐ͗Ϭ͘ϬϬϴϳďďůƐͬŌǆ164 Ōсϭ͘ϰ ďďůƐ /͗Ϭ͘ϬϮϲϰďďůƐͬŌǆ164 Ōсϰ͘ϯ ďďůƐ K͗Ϭ͘ϬϮϵϳďďůƐͬŌǆ164 Ōс4͘ϵďďůƐ ůŝŶĞͬWƵŵƉŝŶŐ– WƵŶĐŚŚŽůĞƐĂŶĚĞƐƚĂďůŝƐŚĐŝƌĐĨŽƌƐƵƌĨĂĐĞƉůƵŐ ϭ͘ Z/,ĂŶĚƉĞƌĨŽƌĂƚĞƚŚƌŽƵŐŚƚƵďŝŶŐĂŶĚƉƌŽĚƵĐƟŽŶĐĂƐŝŶŐ @ 164’ KB Ϯ͘ ƐƚĂďůŝƐŚĐŝƌĐƵůĂƟŽŶĚŽǁŶƚŚĞƚƵďŝŶŐ͕ƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ/ĂŶĚƚŚĞŶƌĞƚƵƌŶƐƵƉƚŚĞK͘ DĂǆ ƉƌĞƐƐƵƌĞϮϬϬϬƉƐŝ͘EŽƚĞƌĂƚĞƐĂŶĚƉƌĞƐƐƵƌĞƐ͘ Ă͘ &ƌŽŵƚŚĞ>ƚŚĞƌĞŝƐƐƚƌŝŶŐǇĐĞŵĞŶƚŝŶƚŚĞ/ĂďŽǀĞĨƌŽŵΕϴϰ͛- ϭϲϰ͛<͘ ď͘ WůĞĂƐĞŶŽƚĞǀŽůƵŵĞƉƵŵƉĞĚǀƐǀŽůƵŵĞƌĞƚƵƌŶĞĚŝŶĞĂĐŚĂŶŶƵůƵƐ͘ ϯ͘ ^ǁĂƉƚŽƉƵŵƉĚŽǁŶK͕ƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉ/͘ŶĚƚŚĞŶƚĂŬĞƌĞƚƵƌŶƐƵƉƚƵďŝŶŐ͘EŽƚĞƌĂƚĞƐĂŶĚ ƉƌĞƐƐƵƌĞƐ͘ ϰ͘ D/d-dǆ/ǆKƚŽϭϱϬϬƉƐŝĂŶĚŐĞƚ>>ZŝĨƚŚĞƌĞŝƐŽŶĞ ϱ͘ /ĨΕϮďƉŵƉƵŵƉƌĂƚĞĂƚфϭϱϬϬƉƐŝŝƐŶŽƚĂĐŚŝĞǀĂďůĞ͕contact Katherine O’Connor dƵďŝŶŐĂŶĚ/ƉůƵŐ WƵŵƉĞƌƐͬĞŵĞŶƚ ϭ͘ ZhƚŽƉƵŵƉĚŽǁŶƚŚĞƚƵďŝŶŐĂŶĚƚĂŬĞƌĞƚƵƌŶƐĨƌŽŵƚŚĞ/;ϳ͟ǆϯ͘ϱ͟ĂŶŶƵůƵƐͿ Ϯ͘ WƵŵƉŝŶŐĚŽǁŶƚŚĞƚƵďŝŶŐƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ/ƉƵŵƉƚŚĞĨŽůůŽǁŝŶŐ͗ Ă͘ ±1ϬďďůƐǁĂƌŵƐĞĂǁĂƚĞƌ ď͘ цϭϬďďůƐƐƵƌĨĂĐƚĂŶƚǁĂƐŚ Đ͘ цϭϬďďůƐƐĞĂǁĂƚĞƌ ϯ͘ /ĨĐůĞĂŶƌĞƚƵƌŶƐĂƌĞŶŽƚƐĞĞŶĂƚƐƵƌĨĂĐĞĨƌŽŵ/ƉƵŵƉĂĚĚŝƟŽŶĂůŇƵŝĚ ϰ͘ ŽŶƟŶƵĞƚĂŬŝŶŐƌĞƚƵƌŶƐĨƌŽŵƚŚĞ/ĂŶĚƉƵŵƉƚŚĞĨŽůůŽǁŝŶŐƐĐŚĞĚƵůĞ͗ Ă͘ цϱďďů&tƐƉĂĐĞƌ ď͘ ±ϳϱ ďďůƐŽĨƉĞƌŵĂĨƌŽƐƚĐĞŵĞŶƚ;ƉůĂŶŶĞĚĞǆĐĞƐƐĨŽƌƉůƵŐŐŝŶŐŽī^ůĞĂŬͿ ϱ͘ KŶĐĞŐŽŽĚƌĞƚƵƌŶƐĂƌĞƐĞĞŶŽƵƚƚŚĞ/ĂƚƐƵƌĨĂĐĞ͕ĐŽŶƟŶƵĞƉƵŵƉŝŶŐĚŽǁŶƚƵďŝŶŐƚŽƐƋƵĞĞǌĞ ƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ ϲ͘ DŝǆŽŶƚŚĞŇǇĂŶĚƉƵŵƉĞǆĐĞƐƐĐĞŵĞŶƚĂƐŶĞĞĚĞĚƚŽŐĞƚŐŽŽĚƌĞƚƵƌŶƐĂĐƌŽƐƐĂůůĂŶŶƵůŝĂŶĚ ƚƵďŝŶŐ KWůƵŐ ^ƵƌĨĂĐĞtŽƌŬ ΘdŽƉ:Žď – ǆĐĂǀĂƚĞǁĞůůŚĞĂĚ͕ĐƵƚŽīďĞůŽǁŐƌĂĚĞ͕ǁĞůůƉůĂƚĞ͕ďĂĐŬĮůů ϭ͘ ,ƚŽƉĞƌĨŽƌŵĚƌĂǁĚŽǁŶƚĞƐƚŽŶƚƵďŝŶŐ͕/ĂŶĚK Ϯ͘ ZĞŵŽǀĞǁĞůůŚŽƵƐĞ͘ ϯ͘ ůĞĞĚŽīdͬ/ͬKƚŽĞŶƐƵƌĞĂůůƉƌĞƐƐƵƌĞŝƐďůĞĚŽīƚŚĞƐǇƐƚĞŵ͘ ϰ͘ ZĞŵŽǀĞƉƌŽĚƵĐƟŽŶƚƌĞĞŝŶƉƌĞƉĂƌĂƟŽŶĨŽƌĞǆĐĂǀĂƟŽŶĂŶĚĐĂƐŝŶŐĐƵƚ͘ ϱ͘ /ĨƐŚĂůůŽǁƚŚĂǁĐŽŶĚŝƟŽŶƐĂƌĞĨŽƵŶĚ͕ŚĂǀĞƐŚŽƌŝŶŐďŽǆŝŶƐƚĂůůĞĚĚƵƌŝŶŐƚŚĞĞǆĐĂǀĂƟŽŶĂĐƟǀŝƚǇƚŽ ƉƌĞǀĞŶƚůŽƐĞŐƌŽƵŶĚĨƌŽŵĨĂůůŝŶŐŝŶƚŽƚŚĞĞǆĐĂǀĂƟŽŶ͘ ϲ͘ ƵƚŽīǁĞůůŚĞĂĚĂŶĚĂůůĐĂƐŝŶŐƐƚƌŝŶŐƐĂƚϰĨĞĞƚďĞůŽǁŽƌŝŐŝŶĂůŐƌŽƵŶĚůĞǀĞů͘ ϳ͘ WĞƌĨŽƌŵƚŽƉũŽďŽŶKĂŶŶƵůƵƐ͘tŝůůŶĞĞĚĂƚůĞĂƐƚϮďďůƐŽĨĐĞŵĞŶƚĨŽƌƚŚĞKƚŽƉũŽď͘ ƐƟŵĂƚĞĚdKŝŶKĂƚϳϬ͛͘ ϴ͘ WĞƌĨŽƌŵƚŽƉũŽďŝĨŶĞĞĚĞĚƚŽĞŶƐƵƌĞĐĞŵĞŶƚŝƐĂƚƐƵƌĨĂĐĞŽŶĂůůƐƚƌŝŶŐƐ͘ K'ǁŝƚŶĞƐƐĂŶĚ ƉŚŽƚŽĚŽĐƵŵĞŶƚƌĞƋƵŝƌĞĚ͘ ϵ͘ ^ĞŶĚƚŚĞĐĂƐŝŶŐŚĞĂĚǁŝƚŚƐƚƵďƚŽŵĂƚĞƌŝĂůƐƐŚŽƉ͘WŚŽƚŽĚŽĐƵŵĞŶƚ͘ ϭϬ͘ tĞůĚϭͬϰΗƚŚŝĐŬĐŽǀĞƌƉůĂƚĞ;ϭϲΗKͿŽǀĞƌĂůůĐĂƐŝŶŐƐƚƌŝŶŐƐǁŝƚŚƚŚĞĨŽůůŽǁŝŶŐŝŶĨŽƌŵĂƟŽŶďĞĂĚ ǁĞůĚĞĚŝŶƚŽƚŚĞƚŽƉ͘WŚŽƚŽĚŽĐƵŵĞŶƚ͘K'ǁŝƚŶĞƐƐƌĞƋƵŝƌĞĚ͘ x ŽŶŽĐŽWŚŝůůŝƉƐ x KRU 2D-01 x Wdη͗ϭϵϮ-103 x W/η͗ϱϬ-103-ϮϬϭϴϱ-00-00 ϭϭ͘ ZĞŵŽǀĞĐĞůůĂƌ͘ĂĐŬĮůůĐĞůůĂƌǁŝƚŚŐƌĂǀĞůͬĮůůĂƐŶĞĞĚĞĚ͘ĂĐŬĮůůƌĞŵĂŝŶŝŶŐŚŽůĞƚŽŐƌŽƵŶĚůĞǀĞů͘ ϭϮ͘ KďƚĂŝŶƐŝƚĞĐůĞĂƌĂŶĐĞĂƉƉƌŽǀĂůĨƌŽŵK'͘ZDK͘ ϭϯ͘ ZĞƉŽƌƚƚŚĞĮŶĂůWΘŚĂƐďĞĞŶĐŽŵƉůĞƚĞĚƚŽƚŚĞK'͘WŚŽƚŽĚŽĐƵŵĞŶƚĮŶĂůůŽĐĂƟŽŶ ĐŽŶĚŝƟŽŶĂŌĞƌǁŽƌŬŝƐĐŽŵƉůĞƚĞĚĐĞŵĞŶƟŶŐƵŶŝƚĂŶĚĂƐƐŽĐŝĂƚĞĚĞƋƵŝƉŵĞŶƚ͘ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:27 Township:11N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:9800 ft MD Lease No.:ADL 0025586 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 117 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 3345 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 9791 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 9374 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bottom 9703 ft 311 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1700 1700 1700 1700 IA 1825 1825 1800 1800 OA 0 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Bailer was found to have chunks of hard cement in it. 3 MITs were performed with inconclusive results (not documented here); the 4th test passed. November 20, 2023 Bob Noble Well Bore Plug & Abandonment KRU 2M-01 ConocoPhillips Alaska Inc. PTD 1921030; Sundry 323-293 none Test Data: P Casing Removal: Brent Rogers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-1120_Plug_Verification_KRU_2M-01_bn              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: ___________________ 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): 9800'9407' 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 written 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): 9339' MD and 5973' TVD 1819' MD and 1782' TVD Perforation Depth TVD (ft): Tubing Size: J-55 9375' 7/1/2023 Packer: Baker FB-1 Packer SSSV: Camco TRDP-4A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025585, ADL0025586 192-103 P.O. Box 100360, Anchorage, AK 99510 50-103-20185-00-00 ConocoPhillips Alaska, Inc. KRU 2M-01 N/A (P&A)Kuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6331' 9345' 5977' 9345' MD 117' 2748' 117' 3344' 6324'9791' 16" 9-5/8" 76' 3305' Perforation Depth MD (ft): 9435-9489' (cemented) 9752' 6044-6085' (cemented) 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 323-293 By Kayla Junke at 9:34 am, May 18, 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: 2023.05.18 07:23:47-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor MDG 6/9/2023 X VTL 6/26/2023 AOGCC inspection required after cutoff and before remedial cementing Well abandonment marker to meet requirements of 20 AAC 25.120 Photo document all steps of surface abandonment X 10-407 DSR-5/18/23BWH 6/26/23 06/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.26 13:49:59 -08'00' RBDMS JSB 062723 2M-01 P&A 1 May 2023 Expected start date: 1 July 2023 Katherine O’Connor Background & ObjecƟve 2M-01 was a Kuparuk A-sand/C-sand producƟon well equipped with 3-1/2” tubing and 7” producƟon casing. In 2012 a CTD lateral program was proposed to increase reservoir exposure and probe the western periphery of 2M pad. The exisƟng perforaƟons were squeezed before coil rigged up on the well. The well was not successfully drilled. There were two failed aƩempts to exist the 7” casing oī of a whipstock set in a cement pilot hole. With no favorable alternative kick off points, the decision was made to rig down CTD and suspend the well. The wells current status is suspended with a reservoir abandonment plug. This well does not meet economics for a RWO so Conoco would like to proceed with permanent plug and abandonment seeing as the well has no future utility. Well Status Suspended with a reservoir cement plug. TOC tagged at 9349’ SLMD on 4/17/2021 There are no other hydrocarbon bearing zones outside the casing Fluid in Hole = Inhibited Seawater Reservoir pressure 3/14/2012 = 3154 psi @ 9460 MD / 6062’ TVD Procedure Eline / Pumping – Intermediate Plug in Tubing and IA 1. RU EL and pumpers, PT equipment as required 2. AƩempt to circulate through the open GLM @ 9286’ RKB down tubing taking returns from the IA 3. If able to pump at least 2 BPM at 2000 psi or less, circulate in 390 bbls 9.8 ppg brine & jump to step 8. 4. If unable to get good circulaƟon through GLM: a. RIH with 4’ tubing punch, 4 spf b. Punch approx. 9200’ RKB (middle jt of tubing) c. Pump down tubing, taking returns up the IA to conĮrm circulaƟon. d. Circulate in 390 bbls of 9.8 brine String Top Bottom Size ID bbls/ft volume ft/bbl notes 3.5" tubing 0 9200 3.5" 9.3# 2.992" 0.0087 80.0 115.0 calc'd from tubing punch 3.5" x 7" annulus (IA) 0 9200 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 243.0 37.9 calc'd from tubing punch 7" x 9-5/8" annulus (OA) 0 3344 7" 26# x 9-5/8" 36# 8.921" x 7" 0.0297 99.4 33.7 5. RU cementers and pump the following schedule down the tubing taking returns from the IA: a. 5 bbl FW spacer b. 270 bbls 15.8 pgg Class G cement (67bbl tubing volume + 203bbl IA volume c. 2 bbl FW spacer d. 5” foam ball e. 12 bbl 9.8 ppg brine displacement 6. TOC should be approximately 1600’ RKB Slickline – Tag TOC & Pressure test 7. WOC for minimum of 24 hours. Notify AOGCC inspector of cement timing and plug tag at least 24 hours in advance 8. RIH and tag TOC @ approx. 1600’ RKB (AOGCC witness) 9. Perform CMIT-TxIA to 1500 psi (AOGCC witness) Eline/Pumping – Punch holes and establish circ for surface plug 10. RIH and punch through tubing and 7” casing at ~750’ RKB, in the middle of joint of tubing 11. Establish circulation down the tubing, taking returns up the IA and then returns up the OA. 12. If ~2bpm pump rate at <2000 psi is not achievable, RBIH and punch ~30’ above previous holes Pumpers/Cementing – Surface Plug 13. RU to pump down the tubing and take returns from the IA (7” x 3.5” annulus) and the OA (9- 5/8” x 7” annulus) 14. Pumping down the tubing taking returns up the OA pump the following (to flush arctic pack) a. ±30 bbls hot diesel b. ±50 bbls warm seawater c. Alternate hot diesel and warm seawater until clean returns are seen at surface 15. Once clean returns are seen at surface and the arctic pack is out of the OA, rig up to cement down the tubing taking returns from the OA then IA 16. Line up to take returns from the OA (once clean cement returns are seen at surface, swap valves to take returns from IA) 17. Pump the following schedule: a. ±10 bbls of surfactant wash b. ±5 bbl FW spacer c. ±75 bbls of permafrost cement (20% excess cement to surface T/I/O = 7 bbls/20 bbls/23 bbls) 18. Once good returns are seen out the OA at surface, swap to take returns from the IA 19. Mix on the fly and pump excess cement as needed to get good returns across all annuli and tubing 20. Wait ±48 hours for cement to cure before moving to surface work Surface Work – Excavate wellhead, cut off below grade, well plate, backfill 21. DHD to perform drawdown test on tubing and IA. 22. Remove well house. 23. Bleed off T/I/O to ensure all pressure is bled off the system. 24. Remove production tree in preparation for excavation and casing cut. 25. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 26. Cut off wellhead and all casing strings at 4 feet below original ground level. 27. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 28. Send the casing head with stub to materials shop. Photo document. 29. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips 2M-01 PTD #: 192-103 API #: 50-103-20185-00-00 30. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 31. Obtain site clearance approval from AOGCC. RDMO. 32. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed cementing unit and associated equipment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y Samantha Carlisle at 3:10 pm, Jan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dts 1/31/2022 JLC 1/31/2022 Jeremy Price Digitally signed by Jeremy Price Date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¶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sŝĐƚŽƌŝĂͲ dŚĂŶŬƐĨŽƌƚŚĞƌĞƉůǇƌĞŐĂƌĚŝŶŐϮDͲϬϭƐƵƐƉĞŶƐŝŽŶƌĞŶĞǁĂů͘ĨƚĞƌĨƵƌƚŚĞƌĚŝƐĐƵƐƐŝŽŶǁŝƚŚƚŚĞZĞƐĞƌǀŽŝƌŶŐŝŶĞĞƌ͕ ďĞůŽǁĂƌĞƚŚĞĂŶƐǁĞƌƐƚŽǇŽƵƌƋƵĞƐƚŝŽŶƐ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŶĞĞĚĂĚĚŝƚŝŽŶĂůŝŶĨŽƌŵĂƚŝŽŶŽƌŚĂǀĞĂŶǇŽƚŚĞƌ ƋƵĞƐƚŝŽŶƐ͘ 'XVW\)UHHERUQ :HOOV,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH ƵƐƚǇ͕ xtŚĞŶǁŝůůƚŚĞĞǀĂůƵĂƚŝŽŶĨŽƌĂƌŝŐǁŽƌŬŽǀĞƌďĞĐŽŵƉůĞƚĞ͍ odŚĞƌĞƐĞƌǀŽŝƌĞŶŐŝŶĞĞƌŝƐĂŶƚŝĐŝƉĂƚŝŶŐůĂƚĞ&ĞďƌƵĂƌǇĂƚƚŚĞǀĞƌǇĞĂƌůŝĞƐƚ͕ďƵƚŵŽƌĞůŝŬĞůǇƚŚĞĞĂƌůǇƉĂƌƚŝŶ DĂƌĐŚƚŽŚĂǀĞĂĨŝŶĂůŝǌĞĚĂŶƐǁĞƌĨƌŽŵďŽƚŚƚŚĞZtKĂŶĚdŐƌŽƵƉŽŶǁŚĞƚŚĞƌϮDͲϬϭǁŝůůďĞĂ ĐĂŶĚŝĚĂƚĞ͘ x/ĨƚŚĞǁŽƌŬŽǀĞƌŝƐĞĐŽŶŽŵŝĐ͕ǁŚĞŶǁŽƵůĚƚŚĞǁŽƌŬŽǀĞƌďĞƐĐŚĞĚƵůĞĚ͍ odŚŝƐŝƐĂƚŽƵŐŚŽŶĞƚŽĂŶƐǁĞƌďĞĐĂƵƐĞƚŚĞZtKƐĐŚĞĚƵůĞŝƐĂĨůƵĐƚƵĂƚŝŶŐƐĐŚĞĚƵůĞĚƵĞƚŽƚŚĞǀĂůƵĞŽĨ ƚŚĞǁĞůůƐĐƵƌƌĞŶƚůǇŽŶƚŚĞůŝƐƚĨŽƌĂZtK͘/ƚǁŝůůĚĞƉĞŶĚŽŶƚŚĞĞĐŽŶŽŵŝĐǀĂůƵĞŽĨƚŚĞĐŽŵƉĞƚŝŶŐǁĞůůƐĂƚ ƚŚĞƚŝŵĞ͘ƵƌƌĞŶƚůǇƚŚĞZtKůŝƐƚƚŚƌŽƵŐŚϮϬϮϮŚĂǀĞĞĐŽŶŽŵŝĐǀĂůƵĞƐŐƌĞĂƚĞƌƚŚĂŶǁŚĂƚ/ǁŽƵůĚ ĂŶƚŝĐŝƉĂƚĞϮDͲϬϭƚŽŚĂǀĞ͕ƐŽƚŚĞůŝŬĞůǇŚŽŽĚŽĨĂϮϬϮϮZtKŝƐǀĞƌǇƐůŝŵ͘ x/ĨƚŚĞǁŽƌŬŽǀĞƌŝƐŶŽƚĞĐŽŶŽŵŝĐ͕ǁŚĞŶǁŝůůƚŚĞWΘďĞƐĐŚĞĚƵůĞĚ͍ o/ĨƚŚĞZtKŝƐĚĞƚĞƌŵŝŶĞĚƚŽďĞƵŶĞĐŽŶŽŵŝĐĂů͕ƚŚĞWΘƉƌŽĐĞƐƐĚĞǀĞůŽƉŵĞŶƚǁŽƵůĚďĞŐŝŶƐŚŽƌƚůǇ ĂĨƚĞƌ͘dŚĞĞǆĞĐƵƚŝŽŶŽĨƚŚĞWΘǁŽƵůĚůŝŬĞůǇĨĂůůůĂƚĞϮϬϮϮƚŽĞĂƌůǇϮϬϮϯ͕ĚĞƉĞŶĚŝŶŐŽŶƌĞƐŽƵƌĐĞ ĂǀĂŝůĂďŝůŝƚǇ͘ dŚĂŶǆ͕ sŝĐƚŽƌŝĂ Victoria Loepp 6HQLRU3HWUROHXP(QJLQHHU 6WDWHRI$ODVND 2LO *DV&RQVHUYDWLRQ&RPPLVVLRQ :WK$YH $QFKRUDJH$. :RUN 9LFWRULD/RHSS#DODVNDJRY &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH &DVLQJ6WULQJV &DVLQJ'HVFULSWLRQ &21'8&725 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH + 7RS7KUHDG :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH - 7RS7KUHDG %7& &DVLQJ'HVFULSWLRQ 352'8&7,21 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH - 7RS7KUHDG %7& 7XELQJ6WULQJV 7XELQJ'HVFULSWLRQ 78%,1* 6WULQJ0D« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'«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y Samantha Carlisle at 9:57 am, Jun 15, 2020 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-11 16:29:47 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conocophillip s.com RBDMS HEW 6/15/2020 VTL 7/27/20 SFD 6/17/2020ADL0025586, DSR-6/15/2020 SFD 6/17/2020 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-11 16:29:00 Foxit PhantomPDF Version: 9.7.0 jan.byrne@con ocophillips.com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uspended Well Inspection Review Report InspectNo: susBDB200517132224 IA: 150 BPV Installed? ❑ Date Inspected: 5/16/2020 VR Plug(s) Installed? Inspector: Brian Bixby Type of Inspection: Subsequent Well Name: KUPARUK RIV UNIT 2M-01 I Date AOGCC Notified: 4/27/2020 Permit Number: 1921030 Operator: ConocoPhillips Alaska, Inc. Suspension Approval: Completion Report Operator Rep: Roger Winter Suspension Date: 6/20/2012Wellbore I Diagram Avail? ❑� Location Verified? ,.❑ Photos Taken? ❑r If Verified, How? Other (specify in comments) ' Offshore? ❑ Well Pressures (psi): Tubing: _ 200 Fluid in Cellar? ❑ IA: 150 BPV Installed? ❑ OA: 25 VR Plug(s) Installed? ❑ Wellhead Condition The wellhead looked to be in good condition and all the valves worked properly and had gauges on them. Condition of Cellar' Good Surrounding Surface Condition The cellar and the surrounding area inside the wellhouse looked to be in good order. No signs if any leaks and clean of any - trash. Oustide snow covered. Comments Location Verified by as -built pad map. Wellhouse still over wellhead. Suprr,; iior Co m;rerris Photos (2). Location should be free of snow and ice for suspended well inspection. Friday, June 5, 2020 Q •t • _• lip I� f' o. ,7 Q • ,Frd rill 3v Regg, James B (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Monday, September 08, 2014 12:30 PM To: Regg, James B (DOA) \�°�j ot( lei I i4 Cc: Senden, R. Tyler; NSK Well Integrity Proj Subject: Suspended Well Inspections CD1-19A (200-040) & 2M-01 (192-103) Attachments: 2M-01 schematic.pdf; CD1-19A schematic.pdf Categories: Red Category Jim, I preparation for the quinquennial suspended well inspections that are due within 24 months of Sept 30th of years ending with a 5 or a 0,ConocoPhillips discovered 2 wells that have not had the initial inspection required within 1 year of the suspension as per 20 AAC25.110(e). CD1-19A(200-040)—was recently re-categorized from a P&A'd well to a suspended well in both the CoP and AOGCC databases and therefore did not originally show up in our system as requiring an inspection. The original suspension completion report was received May 31, 2013.Which means the inspection was due before May 31 2014. 2M-01 (192-103)—was suspended in June 2012(inspection due June 2013)and not properly recorded in our compliance database until the recent audit for wells requiring quinquennial inspections. Both wells are in field and have daily well house and pressure gage inspections. The State Witnessed Inspections will be bundled with other inspection work in the area and completed as soon as practical. ✓ Schematics are attached. Let me know if you have any questions. — E w 44e%Or) 5 p& - MJ I,VQ& t✓1/4-5Pe 61/14-(14- MJ 1/l4-(14- MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 *a MAY 2 2 2015 MJ's Cell (907) 943-1687 SC 1 iti, KUP 2M-01 • CC}ntpcOPiltlIps Well Attributes Max Angle&MD TD AEt It Inc, Wellbore API/UWI Field Name Wellbore Status Inc'V) MD(11581 Act Bt IftKB1 501032018500 i KUPARUK RIVER UNIT PROD 61.81 2,801 74 0.800.0 Comment H2S(ppm) Date Annotation End Date KB-Grd In) Rig Release Date Well contig -2M-o1,2!120138:56:26 AM SSSV:TRDP 25 10/28/2011 Last WO'. 46.02 10/30,1902 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod ByEnd Date Last Tag:SLM 9,528.0 3/12/2012 Rev Reason:WELL SUSPENDED osborl 7/16/2012 Casing Strings Casing Description String 0.. String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String..String Top Thrd �,.�' `„� CONDUCTOR 16 15.060 41.0 _ 117 0 117.0 62.58 H-40 WELDED y i ■ Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ) SURFACE 9 5/8 8,921 39.2 3,344.5 2,748.3 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)... String WL..String... String Top Thrd PRODUCTION 7 6.276 39.2 9,791.0 6,323.9 26.00 J-55 BTC Tubing Strings i Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...string...String Top Thrd TUBING 31/2 2.992 37.6 9,375.2 5,999.3 9.30 J-55 ABM-EUE Completion Details Top Depth (ND) Top Incl Nomi... CONDUCTOR, Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 41-t17 37.6 37.6 0.03 HANGER FMC GEN IV TUBING HANGER 3.500 1,818.8 1,782.1 23.12 SAFETY VLV CAMCOTRDP-4ASSSV 2.812 11 9,338.4 5,972.1 42.72 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSY w/5'EXTRA SPACER TUBE 4.000 _ OD 4.5",ID 2.985" SAFETY VLV, 1,819 9,339.2 5,972.7 42.72 PACKER BAKER FB-1 PACKER w/CROSSOVER 8 SBE(OD 5.0",ID 4.0"SEAL 4.000 BORE) 9,362.6 5,989.9 42.58 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,374.3 5,998.6 42.44 SOS BAKER SHEAR OUT.TTL ELMD @ 9362'SWS LET 11/3/1992 2.992 I. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth 7 (TVD) Top Incl Top(ftKB) (ftKB) CI Description Comment Run Date ID(in) 9,345.0 5,976.9 42.70 CMT SQZ CEMENT SQUEEZE w/17 PPG CLASS G CEMENT, 5/29/2012 0.000 SURFACE, PLACED APPROX 13 BBLS OF CEMENT BEHIND PIPE. 39-3,345 TOC @ 9345'. GAS LIFT, 9,357.0 5,985.8 42.69 TBG PUNCH PERF w/2 IS-HMX-BH,6 SPF,60 DEG PHASE 5/26/2012 2.992 3,450 -, 9,407.0 6,022.8 41.60 FISH Mill,Motor,orienter output shaft,overshot and bait sub, 6/17/2012 0.000 Perforations&Slots IC Shot Top(TVD) Btm(ND) Dens GAS LIFT, 4 ,. Top(ftKB) Btm(ftKB) (ftKB) (855) Zone Date (ah... Type Comment 6.839 9,435.0 9,489.0 6,043.8 6,084.6 C-4,A-3,2M-01 12/18/1992 4.0 IPERF 4 12"Csg Gun,180 deg.phasing Notes:General&Safety ar End Date Annotation GAS LIFT, 3/8/2011 NOTE:View Schematic w/Alaska Schematic9.0 8,545 7/16/2012 NOTE:WELL SUSPENDED,PLANNED SIDETRACK/LATERAL NOT DONE GAS LIFT. 9,119 GAS LIFT, "+^_ 9.286 SEAL ASSY, 9,338 PACKER.9,339 - ", likkt TBG PUNCH, _ 7 9,357 NIPPLE.9.363 - 'I SOS.9,374 --- \ J NA Mandrel Details FISH.9,407 -- . Top Depth i Top i Port S.., (ND) Incl OD Latch Size TRO Run N...Top(ftKB) (ftKB) CI Make Model (in) Sery Valve Type Type lin) (Psi) _ Run Date Com... 1 3,449.8 2,803.4,58.73 CAMCO FMHO 1 GAS LIFT DMY BK 0.000 0.0 5/21/2012 (PERF, 2 6,839.4 4,514.660.65 CAMCO FMHO 1 GAS LIFT DMY INT 0.000 0.0 5212012 i 9.4359,489 chlrsoz. 3 8,545.0 5,414.9 50.92 CAMCO FMHO 1 GAS LIFT DMY BTM 0.000 0.05242012 9' .` 4 9,119.1 5,810.5 42.70CAMCO FMHO 1 GAS LIFT DMY BK 0.000 0.0 12/18/1992 \. 5 9,286.2 5,933.7 42.62 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 2/10/2000 CEMENT,9,345 PRODUCTION, 39-9,791 TD(2M-ot), 9,800 • . • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 - 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Q ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 1.2. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: June 20, 2012 192 - 103 / 312 - 179 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 21, 1992 50 103 - 20185 - 00 ` 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 114' FSL, 19' FWL, Sec. 27, T11N, RO8E, UM October 27, 1992 2M - 01 • Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 1099' FSL, 1098' FEL, Sec. 29, T11N, RO8E, UM GL (ft above MSL): 106' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1143' FSL, 1315' FEL, Sec. 29, T11N, R8E, UM 9345' MD / 5977' TVD Kuparuk River Oil Pool • 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 487859.5 ' y 5948986• Zone 4 • 9800' MD / 6331' TVD ' ADL 25585 • TPI: x - 481462 y - 5949984 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 481248 y 5950029 Zone 4 1819' MD / 1782' TVD 2671 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1400' MD / 1392' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 41' 117' 41' 117' 24" 225 sx PermaFrost C 9.625" 36# J -55 40.5' 3346' 40.5' 2749' 12.25" 564 sx PermaFrost E, 600 sx Class G 7" 26# J -55 33' 9785' 33' 6319' 8.5" 198 sx Class G 24. Open to production or injection? Yes ❑ No In If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 9375' 9339' MD / 5973' TVD perfs squeezed off @ 9345' MD / 5977' TVD s' t® 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. VV DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED �eG ,v 1 :4 . 9345' 13 bbls 17 ppg 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE ,; er0 1t I ", Me R$DMS JUL 18 2012 f1 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE i Z - /f Submit original only 61l.flii-- 4,f2- 28. GEOLOGIC MARKERS (List all formations and nips encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1400' 1392' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS 4\114e Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree @ 265 - 6820 Printed Name . Gantt Title: Alaska CTD Supervisor `I Signature &Ai/ rf Phone 263 - 4021 Date '7 - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 d KUP 2M -01 Conoc 01 Well Attributes Max Angle & MD TD AIriSPCCI, Inc, Wellbore APW WI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (ftKB) 501032018500 KUPARUK RIVER UNIT PROD 61.81 2,801.74 9,800.0 "• - Comment 1425 (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well conrg - zM -0I 7n020/26 AM SSSV: TRDP 25 10/28/2011 Last WO: 46.02 10/30/1992 schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag. SLM 9,528.0 3/12/2012 Rev Reason: WELL REVIEW osborl 7/10/2012 Casing Strings cr Description String Casing Desing O . (t String ID ... Top (ftKB) Set Depth ... Set Depth (TVD) .. String Wt... String String Top Thrd HANGER, as CONDUCTOR 16 15.060 41.0 117.0 117.0 62.58 H WELDED L Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd l SURFACE 9 5/8 8.921 39.2 3,344.5 2748.3 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth )TVD) ... String Wt... String ... String Top Thrd I PRODUCTION 7 6.276 39.2 9,791.0 6,323.9 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 37.6 9,375.2 5,999.3 9.30 J -55 ABM -EUE Completion Details Top Depth - - -- (TVD) Top Inal Nom'... CONDUCTOR, Top (ftKB) (5013) (1 Item Description Comment ID (in) 41 - 117 37.6 37.6 0.03 HANGER FMC GEN IV TUBING HANGER 3.500 _ 1,818.8 1,782.1 23.12 SAFETY VLV CAMCO TRDP -4A SSSV 2.812 9,338.4 5,972.1 42.72 SEAL ASSY BAKER GBH -22 LOCATOR SEAL ASSY w /5' EXTRA SPACER TUBE 4.000 -- OD 4.5 ", ID 2.985" SAFETY VLV, 1.819 9,339.2 5,972.7 42.72 PACKER BAKER FB PACKER w /CROSSOVER & SBE (OD 5.0 ", ID 4.0" SEAL 4.000 L BORE) - 9,362.6 5,989.9 42.58 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,374.3 5998.6 42.44 SOS BAKER SHEAR OUT. TTL ELMD @ 9362' SWS LET 11/3/1992 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) ( ° ) Description Comment Run Date ID (in) 1 9,345.0 5,976.9 42.70 CMT SQZ CEMENT SQUEEZE w/ 17 PPG CLASS G CEMENT, 5/29/2012 0.000 SURFACE, PLACED APPROX 13 BBLS OF CEMENT BEHIND PIPE. 39 - 3,345 TOC @ 9345'. GAS LIFT, 9,357.0 5,985.8 42.69 TBG PUNCH PERF w/ 2" IS- HMX -BH, 6 SPF, 60 DEG PHASE 5/26/2012 2.992 3.450 9 6,022.8 41.60 FISH Mill, Motor, orienter output shaft, overshot and bait sub, 6/17/2012 0.000 I Perforations & Slots Shot Top (TVD) Btm (TVD) Dens GAS LIFT, Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (F1 ... Type Comment 5,839 9,435.0 9,489.0 6043.8 6084.6 C -4, A -3, 2M -01 12/18/1992 4.0 IPERF 4 1/2' Csg Gun, 180 deg. phasing E Notes: General & Safety GAS LIFT, G' End Date Annotation 8,545 - 3/8/2011 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 9.119 FT, r L GAS LIFT, -i 9,286 SEAL S 9,S8 J J 9 I PACKER, 9,339 TBG PUNCH, Ilt 9.357 1 NIPPLE, 9,383 f 505, 9.374 Mandrel Details FISH, 9,407 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,449.8 2,803.4 58.73 CAMCO FMHO 1 GAS LIFT DMY BK 0.000 0.0 5/21/2012 IPERF, - - -- 2 6,839.4 4,514.6 60.65 CAMCO FMHO 1 GAS LIFT DMY INT 0.000 0.0 5/21/2012 9.435-9,489 CMT SOZ, 3 8,545.0 5,414.9 50.92 CAMCO FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/24/2012 9,345 4 9,119.1 5,810.5 42.70 CAMCO FMHO 1 GAS LIFT DMY BK 0.000 0.0 12/18/1992 5 9,286.2 5,933.7 42.62 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/10/2000 CEMENT, 9,345 PRODUCTION, 39 -9,791 4 TD (2M -01), 9,800 2M -01 Pre -Rig Well Work Summary DATE' SUMMARY 5/20/12 BRUSHED & FLUSHED TBG • NIPPLE @ 9362' RKB. SET CA -2 PLU.a 9362' RKB. SET AVA CATCHER ON PLUG. PULLED OV © 8545' RKB; ATTEMPTED PULL GLV @ 6839' RKB. IN PROGRESS. 5/21/12 PULLED GLVs @ 3449' & 6839' RKB. SET DVs @ 3449' RKB & 6839' RKB. OPEN GLM @ 8545' RKB, READY FOR CIRC OUT. IN PROGRESS. 5/23/12 PUMPED 255 BBL INHIBITED SW DOWN TBG UP IA FOLLOWED BY 64 BBL DSL. ALLOW TO U TUBE / BALANCE. ATTEMPTED SET DV @ 8545' RKB, UNSUCCESSFUL. IN PROGRESS. 5/24/12 SET DV @ 8545' RKB. MIT TBG & IA 3000 PSI, PASSED. PULLED CATCHER @ 9313' SLM. PULLED CA -2 PLUG @ 9362' RKB. PUMP INJECTIVITY TEST DOWN TBG, 1/2 BPM @ 450 PSI & 1.5 BPM @ 800 PSI. ATTEMPTED CLOSURE TEST ON SSSV, UNSUCCESSFUL. IN PROGRESS. 5/25/12 BRUSH'n FLUSH SSSV @ 1818' RKB. ATTEMPTED CLOSURE TEST, UNSUCCESSFUL. FLAPPER STUCK OPEN. UNABLE TO BLEED CONTROL LINE PRESSURE BELOW TBG PRESSURE. ATTEMPTED CLOSE SSSV WITH FRICTION TOOL, UNSUCCESSFUL. 5/26/12 LOG SBHP AT MID PERF DEPTH OF 9463' RKB. MEASURED PRESSURE WAS 2926 PSI AND TEMPERATURE OF 158 DEG F. PERFORATE TUBING AT 9357' - 9359', ABOVE NIPPLE. CCL STOP DEPTH 9353.3' CCL TO TOP SHOT 3.8'. GUN SHOT WAS 2" HSC 2' OF 6 SPF 60 DEG PHASED. 5/28/12 MILLED ON D- NIPPLE AT 9335' CTMD. STALLED SEVERAL TIMES UNABLE TO MAKE ANY HEADWAY. POOH TO INSPECT BHA. MILL GAUGED FROM 2.75" TO 2.80 ". WELL FREEZE PROTECTED. RESTART IN A.M. JOB IN PROGRESS. 5/29/12 ATTEMPTED TO MILL "D" NIPPLE AT 9363' MD USING SEAWATER WITH 776 AND 1% BIO, STALLED MULTIPLE TIMES MAKING NO PROGRESS. CT WAS SLIP STICKING. PERFORMED CEMENT SQUEEZE WITH 17 PPG CLASS G CEMENT. PLACED APPROXIMATELY 13 BBLS OF CEMENT BEHIND PIPE. TOP OF CEMENT AT 9345' MD. FREEZE PROTECTED WELL TO 2000 ND. JOB COMPLETE 6/1/12 MIT TBG TO 1500 -PSI (PASSED). TAG CEMENT PLUG @ 9336' SLM. JOB COMPLETE. 6/2/12 PRE -CTD -- TESTED THE SV, SSV, AND MV ON NEGATIVE AND POSITIVE PRESSURE (ALL PASSED), T -POT (PASSED), T -PPPOT (PASSED @ 4650 PSI), FUNCTION TESTED ALL LDS'S 6/3/12 TAG CEMENT AT 9349'. LOG CORRELATED TO JEWELRY • • n Phitli Time Log & Summary Ca oco s p Wel/view Web Reporting Report Well Name: 2M -01 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 6/5/2012 10:00:00 PM Rig Release: 6/20/2012 10:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/05/2012 24 hr Summary Move Rig 3G to 2M, Rig up and start BOPE Test 00:00 17:00 17.00 0 0 MIRU MOVE MOB P Move rig 3G to 2M Pad 17:00 20:00 3.00 0 0 MIRU MOVE MOB P Arrive on 2M, remove jeeps and spot modules 20:00 22:00 2.00 0 0 MIRU MOVE RURD P Begin MIRU 22:00 23:00 1.00 0 0 MIRU WHDBO NUND P Rig Accept @ 22:00, Nipple up BOPE 23:00 00:00 1.00 0 MIRU WHDBO BOPE P Start Full BOPE Test, Witness waived by Lou Grimaldi. AOG(:(' 06/06/2012 Complete BOPE Test, Perform Slack Mgmt, M/U BHA #1 RIH 00:00 06:00 6.00 0 0 MIRU WHDBO BOPE P Full BOPE Test Cont. Romeo 1 failed /passed. 06:00 11:00 5.00 0 0 MIRU WHDBO BOPE P Crew change BOPE test 250 low 3500 psi high. Upper 2" PS rams failed test. replace & re -test. Good test continue with the rest of BOPE test. BOPE test complete. 11:00 13:30 2.50 0 0 MIRU WELLPF CTOP P Remove CT connector, instal E -line boot and pump slack back & test inner reel valve. Clean up rig floor from P- testing. 13:30 16:00 2.50 0 0 MIRU WELLPF MPSP P Set up, test lubricator and pull BPV, 450 psi below. Noticed a leak around the annular, stop & inspect. No issues, just residual fluid behind the lifting ring. 16:00 17:00 1.00 0 0 SLOT WELLPF SFTY P Hold pre -spud meeting with Maddy Crew. 17:00 19:00 2.00 0 0 SLOT WELLPF CTOP P Change out 0-Rings on PDL'sTest TT line & PDL's. 19:00 20:30 1.50 0 0 SLOT WELLPF SLPC P Cut coil to find e-line, 20', test E -Line all good, install CTC and pull test to 35K 20:30 21:24 0.90 0 0 SLOT WELLPF SLPC P Install UQC, PT CTC to 4K PSI 21:24 22:00 0.60 0 0 SLOT WELLPFSFTY P Hold Pre Spud with Corder's crew 22:00 23:30 1.50 0 0 SLOT WELLPF MILL P Pressure up SSSV, Bleed off WHP, PJSM, P/U BHA #1 straight motor and D -331 to mill D nipple, check Pack offs 23:30 23:48 0.30 0 0 SLOT WELLPF MILL P M/U coil to BHA and surface test, stab injector on to well 23:48 00:00 0.20 0 200 SLOT WELLPF MILL P Trip in well, EDC open @ 1 BPM Page 1 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/07/2012 24 hr Summary Mill Nipple, Mill cement pilot hole to 9475 00:00 01:54 1.90 200 9,315 SLOT WELLPF MILL P Tripping in to mill D Nipple 01:54 02:12 0.30 9,315 9,341 SLOT WELLPF MILL P Log K -1 marker for -19', tag up at 9341' corrected, Shut EDC, PUW =50K with pumps off 02:12 06:12 4.00 9,330 9,375 SLOT WELLPF MILL P Pumps on line @ 1.5 BPM @ 2930 PSI FS, RIH to mill cement, Tag A 9338. stall @ 9338.59, 9341.5, establish 10 -15 FPH ROP, cement on shaker. 06:12 06:57 0.75 9,375 9,375 SLOT WELLPF MILL P Crew change - back ream up - 60K stall @ 9352' - P/U weight Crew change - Start adding 776 to system 56K. P/U to 9300' RIH clean milling pass down. P/U weight 56K Motor work through D- nipple area. Corkscrew tubing has up locked in. Cold fluid in route current fluid temp 80 degrees. 06:57 08:57 2.00 9,350 9,348 SLOT WELLPF MILL T Bleed down IA to zero, OA to 300. Open EDC & circ B/U with 776 SW. Cold fluid enroute to rig. Close EDC. Cycle pipe, no luck. Very little WOB transfer -1.2K, Pulling 60K - Pushing 5K. Shut choke - trap 300 psi and try to cycle. No - luck. Fluid temp 84 degrees. Cold fluid on location. 08:57 10:27 1.50 9,348 9,375 SLOT WELLPF MILL T Open EDC - Start pumping 8.8 flo -pro current in MM temperature 65 degrees. Out MM 81 degrees. Complete B/U flo -pro in MM 65 / Out MM 68 degree. Close EDC. Cycle pipe, able to move up 3 ft, WOB -6K, RIH able to move free and pump through bit. P/U weight 45K. POOH 10:27 12:57 2.50 9,375 62 SLOT WELLPF MILL P POOH laying in fluid. Start ordering 40 degree fluid flo -pro for milling & drilling operations. 12:57 13:57 1.00 62 0 SLOT WELLPF MILL P PJSM for laying down BHA. No -flow. lay down BHA & service injector. Inspect drive motor shafts. Mill guage 2.80" Go / 2.79 No -go. Injector looked good. 13:57 14:57 1.00 0 62 PROD1 WHPST PULD P P/U BHA # 2 with .6 ako motor and D331 with smooth • _u•e mill. 14:57 16:57 2.00 62 9,376 PROD1 WHPST TRIP P RIH pumping .4 bpm. In MM 69 degrees / Out MM 75. Weight check @ 8000' - 35K. RIH 9330' Tie in -25ft P/U weight 45K. 16:57 18:00 1.05 9,376 9,395 PROD1 WHPST MILL P In MM 69 deg / Out MM 74 deg. Start milling 1.5 bpm, 3200 psi, ROP 14, BHP 3443, WOB .9, Ct weight 14K. 20 ROHS, diff press 580 psi. Page 2 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 23:15 5.25 9,395 9,475 PROD1 WHPST MILL P Crew change, Stall 0, 9395, PUW =47K, ROP =15 -19 FPH after getting back on bottom, 1.5 BPM @ 3200 PSI FS 23:15 23:45 0.50 9,475 9,333 PROD1 WHPST REAM P Back ream pilot hole, PUW =49K, Dragging 44K , clean trip up to tie in point 23:45 00:00 0.25 9,333 9,368 PROD1 WHPST DLOG P Tie in for +1 foot correction X6/08/2012 Run Dummy Whipstock, Set Whipstock TOWS 9435, Start BOPE Test, Witness waived by L. Grimaldi, AOGCC 00:00 00:48 0.80 9,368 9,298 PROD1 WHPST REAM P RIH, log GR Kalubic - C4 interface. Dry drift pilot hole, PUW =49K 00:48 01:06 0.30 9,298 9,298 PROD1 WHPST OWFF P Perform 15 Min no flow test, 01:06 03:21 2.25 9,298 63 PROD1 WHPST TRIP P Trip out for dummy whipstock, PUW =46K 03:21 04:21 1.00 63 71 PROD1 WHPST PULD P At surface, PJSM while flow checking well. Lay dow BHA #2 .6 degree motor and D -331, Mill out @ 2.78 No Go, for BHA #3 Dummy Whipstock, Tag up and set counters 04:21 07:21 3.00 71 9,476 PROD1 RPEQP1TRIP P Trip in with dummy whipstock. 9323.5 tie in K -1. Tie in correction -24.5' RIH, log the GR in Kalubic (9435'). Tag bottom 9476' min. pump rate. P/U weight 47K. RIH do a CCL log of 7" casing. top two collars. 07:21 09:21 2.00 9,476 71 PROD1 RPEQP1TRIP P POOH. tag up at surface. 09:21 10:21 1.00 71 71 PROD1 RPEQP1 PULD P PJSM, flow check. lay down BHA & P/U BHA # 4 with 2 5/8" Mono bore WS with cement slip. 10:21 13:21 3.00 71 9,455 PROD1 RPEQP1TRIP P Rlh with EDC open pumping .3 bpm. Tie in - 27.5'. RIH to setting depth TOWS 9435 HS. Close EDC - P/U string weight 42K and set. Pressure up to 4000psi. set, 1.8K WOB. Set down to 4.5K WOB 13:21 15:51 2.50 9,455 71 PROD1 WHPST TRIP P POOH pumping. 15:51 17:30 1.65 71 0 PROD1 WHPST PULD P PJSM - lay down BHA. Jet stack with nozzle & stinger. Grease tree & purge stack. 17:30 19:30 2.00 0 0 PROD1 WELLPF RGRP T Change out Bravo 8 valve. PIA 312-" NAD 2 Hours Billable repair hours zq 19:30 20:00 0.50 0 0 PROD1 WHDBO BOPE P Prep for BOPE test, Pull QTS, J confirm stack measurements 20:00 00:00 4.00 0 0 PROD1 WHDBO BOPE P Start BOPE Test. PTD pressure test low 250 / High 4000 psi. Witness waived by Lou Grimaldi, AOGCC 36/09/2012 Test BOPE, Mill window and rathole 00:00 06:00 6.00 0 0 PROD1 WHDBO BOPE P Continue BOPE Test. low 250 / high 4000 psi 1\l'e tA) p TD Page 3 of 12 �' —�� Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 PROD1 WHDBO BOPE P Crew change - complete final two tests. Remove CV & test inner reel valve. BOP Test Complete. 08:00 09:00 1.00 0 73 PROD1 WHPST PULD P PJSM - valve checklist. P/U BHA # 5 with 2.80" window milling BHA. 09:00 12:00 3.00 73 9,435 PROD1 WHPST TRIP P RIH pumping . 3 bpm. Tie in - 24.5. PU weight 44k, temp: 73° in fluid, 73° out fluid. RIH dry tag @ 9435' P/U 51K 12:00 18:00 6.00 9,434 9,440 PROD1 WHPST MILL P 9434. 20' Start milling - 1.5 bpm, 3200 free spin, BHP 3440, IA zero, OA 320, WOB .3K, Ct weight 17K. temp in 68 / Temp out 72. Midpoint = 9436.5' Exit BOW = 9438.6' Time mill to 9440' Current temp in 75 / out 79 one pit system for milling. 18:00 20:30 2.50 9,440 9,450 PROD1 WHPST MILL P Crew change, continue milling rat hole to 9450 20:30 21:00 0.50 9,450 9,435 PROD1 WHPST DRLG P End of rathole, Back ream window, 1.5 BPM @ 3320 PSI FS, PUW =47.5 K Temps In =85.2 Out =86.7 21:00 22:00 1.00 9,435 9,449 PROD1 WHPST CIRC P Made three reaming passes while swapping to new cold Flo Pro PUWs =49K, 49K, and 51K from 9449. Last PUW @ 51K was no pump. 22:00 22:48 0.80 9,449 9,449 PROD1 WHPST CIRC P 2200 PUW =48K 1.55 BPM Temp in 58.4 Out 81.9 (20 BBIs Out of coil) 2220 PUW =47K 1.55 BPM Temp in 57.9 Out 72.5 New Mud Around 2250 PUW 51K Pumps off, Temp in 57.9 Out 72.5 Dry drift window up 22:48 00:00 1.20 9,449 2,780 PROD1 WHPST TRIP P POOH for BHA # 6,PUW =51 K no pumps Temps @ 3500' are 60.7 in, 71.4 out 06/10/2012 Trip out for Build section BHA. RIH unable to drill, POOH for caliper run 00:00 00:45 0.75 2,780 38 PROD1 WHPST TRIP P Trip out of well, (cont.), 1000' temp, In =61.7, Out =70.7 00:45 02:00 1.25 38 0 PROD1 WHPST PULD P PJSM, Lay Down window milling BHA #5, Mill and reamer @ 2.79 No Go 02:00 03:15 1.25 0 72 PROD1 DRILL PULD P M/U BHA #6, 2.3 degree motor and RR hughes Bi- center, M/U to Coil and surface test 03:15 04:30 1.25 72 5,000 PROD1 DRILL TRIP P RIH, EDC Shut 04:30 06:00 1.50 5,000 9,450 PROD1 DRILL TRIP P Tripping in .25 BPM in, Temp In =64.7, Out 70.6. Tie in - 22.5 ft correction. RIH through window. Page 4 of 12 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 9,450 9,475 PROD1 DRILL DRLG P Start drilling build section - TF interference had 4 stalls during drilling first 20ft. ROP 80 -120 with light WOB, try to set weight down it stalls. P/U weight 50K without pumps. Clean ditch magnets to watch for casing tracking. Quick look at samples look like cement and ashpaltine(scale) chips. 07:00 09:00 2.00 9,475 9,475 PROD1 DRILL CIRC T P/U into cased hole, Over pull through window -3K. popped through, min rate to TOC. Open EDC - circ B /U, Call town, Not sure of inside or outside casing. 09:00 11:00 2.00 9,455 9,430 PROD1 DRILL CIRC T RIH to try & drill another 50' - bobble through window - set down © 9451' - P/U weight 50K, RIH min rate from 9445' - tag @ 9451', 9455' WOB 2K, P/U through window area - Over pull 4.8K from 9435 - 9431'. P/U above TOC. conference call. 11:00 12:00 1.00 9,430 9,200 PROD1 DRILL DLOG T Log Near bit inclination from TOWS to 9100' - No -flow test, Open EDC 12:00 15:30 3.50 9,200 72 PROD1 DRILL TRIP T POOH - Bit catching on collars while POOH, increase in cement cutting @ 1800', light siltstone, metal cuttings & scale, increase pump rate to 1.2 bpm from .7 bpm. 15:30 17:00 1.50 72 0 PROD1 DRILL PULD T PJSM - 15 minute no -flow, lay down BHA. Plenty of metal shavings on BHA & coil connector. Bi- center bit reamers are worn down. 17:00 18:00 1.00 0 0 PROD1 DRILL SFTY P Start setting up rig floor for HES E -line run. Safety meeting with HES for spotting equipment, Crew change. 18:00 20:00 2.00 0 0 PROD1 DRILL ELOG T HES Rigging pack off - Head. preping for R/U 20:00 20:30 0.50 0 0 PROD1 DRILL ELOG T Safety planning meeting for E -Line rig up 20:30 21:30 1.00 0 0 PROD1 DRILL ELOG T Rig Up E -Line 21:30 00:00 2.50 0 9,456 PROD1 DRILL ELOG T RIH with E -Line, Log K -1 and set depth, Make three caliper passes from 9456', Unable to get any deeper. Unable to see RA marker in whipstock tray. Trip out to reconfig TS 06/11/2012 Run HES Caliper through whipstock / window area, Run Hook to fish Whipstock. Run Gamma for RA tie in. 00:00 00:45 0.75 5,000 0 PROD1 DRILL ELOG T Continue tripping out with E -Line 00:45 01:15 0.50 0 0 PROD1 DRILL ELOG T At surface, PJSM, remove caliper from tool string to lower bottom of tool to gamma to find RA marker on tray 01:15 03:00 1.75 0 9,450 PROD1 DRILL ELOG T RIH, tie into K -1 marker, log RA @ 9442, TOWS =9435, Trip out of well Page 5 of 12 Time Logs • • Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 03:00 04:30 1.50 9,450 0 PROD1 DRILL ELOG T At Surcace PJSM, Rig Down HES E -Line service 04:30 07:30 3.00 0 0 PROD1 DRILL CTOP T Processing data, interpreting data. Stand by for plan forward 07:30 11:30 4.00 63 9,450 PROD1 DRILL TRIP T PJSM - P/U J -hook assembly, slow down through restrictions & GLM. Tie in minus 23.5. Increase pump rate to 1.5 bpm, 3200 psi, P/U weight 46K RIH. Orient 45 LOHS - P/U weight 49K prior to window, RIH to 9450' No set down, P/U 48K. 11:30 15:00 3.50 9,450 9,440 PROD1 DRILL FISH T Start fishing - Orient to 180 ROHS, set down WOB 9436' 4K, P/U weight 51 K, minus 1K WOB, dropped off. RIH seen weight @ 9437 - set down WOB 5K, P/U 48K. Rlh to 9455' tag P/U 50K. Might have shift WS. Try 170, 299, 175, 165, 10. No luck Shut down pump - try dry due to cycles. Restart 45 LOHS. Try 180, 185, 190, 195, 205, 210, 220, 250, & 70. No luck Total of 26% CT life. 15:00 18:00 3.00 9,440 0 PROD1 DRILL TRIP T POOH pumping 1.3 bpm. to inspect BHA. Getting hung up on GLM. 18:00 20:00 2.00 0 41 PROD1 DRILL PULD T Crew change out, At surface, Flow check well, Swap out hook for Smart Nozzle, surface test tollstrin 20:00 22:42 2.70 41 9,315 PROD1 DRILL TRIP T Trip in hole 22:42 22:48 0.10 9,315 9,335 PROD1 DRILL DLOG T Log Gamma tie in for -25' correction 22:48 22:54 0.10 9,335 9,430 PROD1 DRILL TRIP T RIH to log whipstock RA, Wt Check =48K 22:54 23:18 0.40 9,430 9,453 PROD1 DRILL DLOG T Log RA Marker, Log down to 9453, Gamma @ 3.56' up, Unable to detect RA marker. Gamma depth 9449'. Double check all parameters and relog, Same setdown depth @ 9453 No RA marker logged. 23:18 00:00 0.70 9,453 6,780 PROD1 DRILL TRIP T Trip out of well 06/12/2012 Attempt to move whipstock down hole with hip- tripper and jarring. Tagging up at 9448' while jarring down 00:00 01:30 1.50 6,780 8 PROD1 DRILL TRIP T Tripping out of well 01:30 02:30 1.00 8 0 PROD1 DRILL PULD T At surface, PJSM, Lay down BHA #8 02:30 03:30 1.00 0 96 PROD1 DRILL PULD T PJSM, M/U BHA #9 2.70 Blind Box, 2 degree bent sub, Hip Tripper, Bi Directional jars, 1 Jt 2 1/16 CS /H and coil track tools, M/U to coil surface test and stab on injector. 03:30 06:30 3.00 96 9,451 PROD1 DRILL TRIP T RIH with EDC closed. Tie in -26ft. P/U weight 49K. Rlh to tag min. rate. Tag @ 9451'. Page 6 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 08:00 1.50 9,451 9,451 PROD1 DRILL FISH T Increase pump to 1.3 bpm, RIH tag /stall 9453' 6K WOB. P/U weight 49K. Hammer down beside tray or into cement? had to jar out 57K ct weight. Start tapping down @ 9450.2' - WOB 1 K, / stop 9451' 3.9K WOB. Try dry again set down 5K @ 9453' . Coiltrak starting to lose comms. 08:00 09:00 1.00 9,451 9,451 PROD1 DRILL FISH T Continue tapping - 1.2 bpm, 3400 psi, Ct weight 16K, down to 14K, made a little footage 1/2 ft.. No more movement. Call town POOH. 09:00 10:45 1.75 9,300 64 PROD1 DRILL TRIP T Open EDC - POOH. 10:45 12:51 2.10 64 91 PROD1 DRILL PULD T At Surface, PJSM, Flow check well, Pull Hip tripper from tool string for rerun. 12:51 15:09 2.30 91 9,375 PROD1 DRILL TRIP T RIH 15:09 15:27 0.30 9,375 9,410 PROD1 DRILL DLOG T Log K -1 for -26', PUW =48K, Pumping .3 Cirp press =930 PSI. PUW =54K with pumps off 15:27 16:33 1.10 9,410 9,452 PROD1 DRILL TRIP T RIH Low side to tag depth @ 9452, PUW =54K, start orienting in 20 degree intervals, All setdowns -9452 DHWOB -4K. Setdown at 0 degrees was 9448', 5K DHWOB. 16:33 16:57 0.40 9,452 9,448 PROD1 DRILL FISH T Roll TF up to high side, attempt to duplicate 9448' set down. PUH to 9420, Pump @ 1.5 BPM to cock jars, RIH and set down @ 9447 stack on 5K 16:57 17:30 0.55 9,448 9,448 PROD1 DRILL FISH T Jars never fired down, PUH to 9420 pump @ 1.8 BPM to cock jars, Set back down to 9448, 4.5K down 17:30 19:30 2.00 9,448 9,448 PROD1 DRILL FISH T Hit ten jar licks down with no apparent movement. 19:30 23:00 3.50 9,448 0 PROD1 DRILL TRIP T Spot 5 Bbls.l0ppg brine on bottom and POOH 23:00 00:00 1.00 0 0 PROD1 DRILL PULD T Lay down fishing tools 36/13/2012 Ran E -line gamma and caliper logs, Whipstock has moved downhole. Prepare for cementing operations 00:00 00:30 0.50 0 0 PROD1 DRILL SFTY T PJSM for e-line operations 00:30 01:42 1.20 0 0 PROD1 DRILL ELOG T RU HES e-line. 01:42 04:42 3.00 0 0 PROD1 DRILL ELOG T Run gamma log with GR .72' from end of toolstring. Tag at 9452' PUW, no RA marker seen on logs. 04:42 08:30 3.80 0 0 PROD1 DRILL ELOG T Run caliper log, Tag up @ 9452 corrected to K -1, Make three logging passes, POOH 08:30 10:00 1.50 0 0 PROD1 DRILL ELOG T At surface, flow check well, PJSM. R/D HES E -Line unit 10:00 15:00 5.00 0 0 PROD1 DRILL OTHR T Evaluate data, prep pits and coil for cement job 15:00 15:30 0.50 0 4 PROD1 DRILL PULD T PJSM, P/U BHA # 11, 2.230 Sand dump nozzle, .5" bottom port, on LQ Blind sub Page 7 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:30 3.00 4 9,461 PROD1 DRILL TRIP T RIH 18:30 19:30 1.00 9,461 9,350 PROD1 DRILL CIRC T Tag up @ 9461, 9446 on Acadamy, Made no correction to bottom which is —9452. for a -9', PUH and circulate well to seawater while jetting cement pilot hole 19:30 21:30 2.00 9,350 9,350 PROD1 DRILL OTHR T Waiting on Schlumberger Cementers 21:30 22:00 0.50 9,350 9,350 PROD1 DRILL SFTY T PJSM with Cement crew 22:00 23:30 1.50 9,350 9,350 PROD1 DRILL CMNT T RU Schlumberger Cementing equipment 23:30 00:00 0.50 9,350 9,350 PROD1 DRILL CMNT T PT Schlumberger cement equipment to 4500 PSI 06/14/2012 Cemented pilot hole, swap reels, change out injector skates. 00:00 01:00 1.00 9,350 9,450 PROD1 DRILL CMNT T Circulate 10 bbls of chemical wash, PUW 47K 01:00 02:12 1.20 9,450 8,300 PROD1 DRILL CMNT T Pump 8 Bbls 17ppg cement, .9 BPM, 1800 CTP, chase with 10 Bbls water followed by Biozan. Circulate 3 Bbls cement around nozzle, lay in cement from 9450' to 8600'. 51 K PUW 02:12 02:42 0.50 8,300 9,350 PROD1 DRILL CMNT T Contaminate cement to9350' with biozan circulating at 1.5 BPM, 3100 CTP, 11K RIW 02:42 03:24 0.70 9,350 8,600 PROD1 DRILL CMNT T PUH jetting with Biozan, 63K PUW 03:24 03:48 0.40 8,600 9,350 PROD1 DRILL CMNT T RBIH, 11K RIW, chase biozan with water. 03:48 06:18 2.50 9,350 0 PROD1 DRILL CMNT T POOH, 62K PUW 06:18 07:18 1.00 0 0 PROD1 DRILL CMNT T At Surface, PJSM, Swap out nozzle for swizzle stick. Jet stack, flush rig, swap back to nozzle for N2 Reel blowdown 07:18 07:48 0.50 0 0 PROD1 DRILL SFTY T PJSM with SLB N2 pumpers 07:48 09:00 1.20 0 0 PROD1 DRILL OTHR T PT N2 to 4K, Pump N2 down coil, Bleed off N2, test wire after unstabbing, test failed 09:00 00:00 15.00 0 0 PROD1 DRILL CTOP T PJSM, Unstab coil and prep for CT string swap / PJSM Swap out injector skates while waiting on cement 06/15/2012 Finish reel swap, iron RU. Test BOP 00:00 05:00 5.00 0 0 PROD1 DRILL CTOP T Continue with reel swap operations, stab coil to injector, MU inner reel iron, install depth counters 05:00 08:00 3.00 0 0 PROD1 DRILL CTOP T MU pressure bulkhead, Prep for BOPE Test, Grease chokes, skate and stack. Clean floor after skate swap, Service shaker 08:00 11:00 3.00 0 0 PROD1 DRILL CTOP T Unable to get test on bulkhead collector to test, 3 Hrs Billable rig repair time Page 8 of 12 • • Time Logs Date From . To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 22:00 11.00 0 0 PROD1 DRILL BOPE T Start Full BOPE Test, Witnessed by John Crisp, AOGCC. Call out grease crew for swab valves. 22:00 22:24 0.40 0 0 PROD1 DRILL SFTY T PJSM for pumping slack 22:24 00:00 1.60 0 0 PROD1 DRILL SLPC T Dress end of a -line, stab onto well and fill coil with water, pump slack at 4000 PSI and 2.4 BPM, test inner reel valve and stripper 06/16/2012 Finished BOP test, pumped slack, cut 1000' CT, rehead and RIH. Mill cement pilot hole from 9357' down to 9439'. Stuck pipe at 9418' 00:00 01:00 1.00 0 0 PROD1 DRILL BOPE T Attempt to retest annular preventer after rebuilding the Koomey Regulator. Fail. 01:00 06:45 5.75 0 0 PROD1 DRILL SLPC T Cut 1000' of CT, found wire at 30'. Install CTC, pull test 30K. Rehead and install UQC. PT CTC to 4000 psi. ( Rebuilt annular preventer and tested good) Complete draw down test 06:45 07:30 0.75 0 0 PROD1 DRILL CTOP T Rehaead UQC, Meg Test wire, PT to 4K 07:30 09:30 2.00 0 62 PROD1 WHPST PULD T PJSM, P/U BHA #12 to mill cement pilot hole, .9 Degree AKO with slick gauge D -331 with up cutters, Make up to coil and surface test, Tag up and set counters, EDC Open, pump >1BPM 09:30 13:30 4.00 62 9,200 PROD1 WHPST TRIP T Trip in hole, Monitor injector reel and pipe. Do frequent pick ups to ensure no damage to coil. Add additional silicone to stuffing box to sump seal 13:30 14:30 1.00 9,200 9,200 PROD1 WHPST TRIP T Stop and shut EDC coil on Biozan, Investigate injector noises. Appears to be gripper blocks popping off pipe 14:30 14:48 0.30 9,200 9,259 PROD1 WHPST DLOG T Log into formation for -2' correction 14:48 15:00 0.20 9,259 9,356 PROD1 WHPST TRIP T Trip in to find TOC, saw K -1 before tag up, Log K -1 from 9350, PUW =57K Added 1 drum safelube 15:00 15:18 0.30 9,358 9,363 PROD1 WHPST MILL T 9357', Tag up with motor work, 1.4 BPM @ 2880. RIW =14K, 20 ROHS, ROP =22 with 1.9K WOB 15:18 15:42 0.40 9,363 9,371 PROD1 WHPST MILL T Loose WOB and Differential, assume D nipple, Pick up wt 55K, RBIH to mill 15:42 18:12 2.50 9,371 9,371 PROD1 WHPST MILL T 9371' stall, PUW =62K, Safe lube all around. Add second drum to system, 1.42 BPM @ 2610 PSI FS, RIW =12K, Stall multiple times @ 9370.9 18:12 18:48 0.60 9,371 9,374 PROD1 WHPST MILL T Ream hole from 9350' continuously varying the TF 18:48 21:48 3.00 9,374 9,439 PROD1 WHPST MILL T Milling cement , 20R , 25 -30 FPH at 1.6 BPM, 2930 CTP, 1.5 - 2K. Stall at 9429', 60K PUW with pump down Page 9 of 12 • • Time Logs - Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:48 23:36 1.80 9,439 9,421 PROD1 WHPST MILL T At 9439' lost ROP with 3K WOB. 70K PUW, recip pipe, started flo -pro down coil, While attempting to pull above the cement top pulled up to 82K, RBIH and stalled motor, Work pipe to free up bit with no success. continue circ flo -pro back to surface. 23:36 00:00 0.40 9,421 9,420 PROD1 WHPST MILL T With flo -pro returns to surface attempt to work free, 9412' at 82K and -18K WOB, 9421' with 15K and 8K WOB. 06/17/2012 Attempted to free stuck BHA with lubricants and cold fluid. Disconnected from BHA. Fished BHA which parted at the HOT leaving 13.6' of fish in the hole at 9410' top of fish. 00:00 01:42 1.70 9,420 9,420 PROD1 WHPST MILL T Continue working pipe,Up 9412' at 82K and -18K WOB, down 9421' with 15K and 8K WOB. 01:42 03:24 1.70 9,420 9,420 PROD1 WHPST MILL T Open EDC and mix up flo -pro pill with 1% lo-torq and 3% lube 776. Spot pill on back side. 03:24 08:24 5.00 9,420 9,420 PROD1 WHPST MILL T With lube pill in annulus close EDC and attempt to pull free, 82K PUW for -19.5 WOB, 9408' Waiting on cold flo -pro 08:24 09:42 1.30 9,420 9,420 PROD1 WHPST MILL T Cold flow pro loaded in pit. Cycle pipe +75 to +5, DHWOB 7K to -19k. Still stuck open EDC at neutral weight, Pump 48 degree flo pro down hole, BHT =152 Out temp =73 09:42 09:54 0.20 9,420 9,420 PROD1 WHPST MILL T Fluid circulated around, Temps 48 in 63 out after 80 BBIs pumped, no change in DHTemp @ 152, Temps stabilized Shut EDC 09:54 10:30 0.60 9,420 9,420 PROD1 WHPST MILL T Work pipe 80K up, 5K down DHWOB -20 to +8, Torque up orienter, Pressure up with pump, try rapid bleed offs No Luck 10:30 13:36 3.10 9,420 89 PROD1 WHPST MILL T Go to neutral weight, bleed off pump pressure, Release BHA, POOH, Left 46.96' of tools in well, Estimate TOF @ 9371 13:36 15:54 2.30 89 69 PROD1 WHPST PULD T At surface, PJSM, flow check well, lay down BHA #12 partial string, P/U BHA #13 fishing string, Inspect injector change out pack offs 15:54 18:06 2.20 69 9,210 PROD1 WHPST TRIP T Trip in with BHA #13, Fishing string 18:06 18:42 0.60 9,210 9,255 PROD1 WHPST DLOG T Tie in to formation, -10' 18:42 19:36 0.90 9,255 9,377 PROD1 WHPST FISH T Close EDC, 14K RIW, 47K PUW, Latch fish at 9377', Pull up 56K with -6K WOB, 9365', Jars fired and overpulled to -8K WOB. Jar down, 8K WOB, 9378', no movement. Jar up and down four times and pulled free. same depth RIH no more overpulls. 19:36 21:36 2.00 9,377 0 PROD1 WHPST TRIP T POOH pumping down backside. Page 10 of 12 � r • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:36 21:54 0.30 0 0 PROD1 WHPST SFTY T PJSM 21:54 22:36 0.70 0 0 PROD1 WHPST PULD T Lay down fishing BHA, Milling BHA parted at the HOT, 13.33' of fish in the hole at 9410' top of fish 22:36 00:00 1.40 0 PROD1 WHPST OTHR T Waiting on fishing tools from deadhorse, injector maintenance and service rig 06/18/2012 Attempted to fish output shaft, overshot with baitsub added to fish. POOH for pipe management, cut 200' of CT 00:00 03:00 3.00 0 0 PROD1 WHPST OTHR T Continue waiting for fishing tools 03:00 03:24 0.40 0 0 PROD1 WHPST SFTY T PJSM 03:24 04:00 0.60 0 0 PROD1 WHPST PULD T MU fishing BHA 04:00 06:30 2.50 0 0 PROD1 WHPST TRIP T RIH 06:30 06:42 0.20 9,210 9,413 PROD1 WHPST DLOG T Run tie -in log, -10'. 06:42 09:30 2.80 9,413 9,413 PROD1 WHPST FISH T Latch fish @ 8413'. Pipe life @ 21 %. Begin jarring, 76K PUW. 15K @ bit. Good jar action. 15 licks down, 29 licks up. Pipe life @ 25 %; discuss with town. 09:30 10:30 1.00 9,413 9,413 PROD1 WHPST FISH T Shut down with pipe in tension, 76K #, let jars cool and wait on orders. 10:30 11:30 1.00 9,413 9,413 PROD1 WHPST FISH T Hit 3 more up jar licks @ 76k, 16k at bit. No movement. Disconnect from fish. Note: Fish length = 15.49' 11:30 13:00 1.50 9,413 0 PROD1 WHPST TRIP T Begin POOH. 13:00 15:30 2.50 0 0 PROD1 WHPST PULD T At surface. Lay down fishing BHA and prep for pipe management. 15:30 19:00 3.50 0 0 PROD1 WHPST CTOP T Displace coil with FW. Pump slack. Cut 200' for pipe management. Found wire at 33' cut. Crew change out 19:00 22:18 3.30 0 0 PROD1 WHPST CTOP T MU CTC, Pull test to 35K, MU UQC, PT to 4000 PSI 22:18 23:18 1.00 0 0 PROD1 WHPST PULD T MU Fishing BHA 23:18 00:00 0.70 0 3,300 PROD1 WHPST TRIP T RIH 06/19/2012 Attempted to fish stuck BHA with Hipp Tripper. Unsuccessful. POOH. PU /MU /RIH with nozzle BHA, Swap well to seawater and freeze protect well. Blow down rig and CT, set BPV. Prepare to swap reels. 00:00 01:12 1.20 3,300 9,217 PROD1 WHPST TRIP T Continue RIH 01:12 01:30 0.30 9,217 9,250 PROD1 WHPST DLOG T tie in to formation, -10.5' 01:30 04:30 3.00 9,250 9,407 PROD1 WHPST FISH T Close EDC, 15K RIW, 49K PUW, tag fish at 9407', start hip tripper going in hole. Stick/slip causing difficulty getting consistent WOB. Attempt to move fish downhole; no movement. 04:30 06:30 2.00 9,407 0 PROD1 WHPST TRIP T POOH Page 11 of 12 • • Time Logs Date From To _ Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:30 1.00 0 0 PROD1 WHPST PULD T At surface. Lay down fishing BHA. Discuss options with town; will be suspending drilling ops and moving off. Install nozzle. 07:30 08:30 1.00 0 0 PROD1 WHPST SVRG T Service rig. Prep for move /summer maint. 08:30 15:30 7.00 0 0 DEMOB WELLPF DISP T Begin RIH to bottom to swap hole to SW & diesel freeze protect from 2500' to surface. 15:30 16:12 0.70 0 0 DEMOB WELLPF PULD T Lay down FP BHA, PU jetting nozzle 16:12 18:00 1.80 0 0 DEMOB WHDBO PULD T Flush stack and surface lines, pump corrosion inhibit 18:00 18:30 0.50 0 0 DEMOB WHDBO SFTY T Crew change, PJSM 18:30 20:30 2.00 0 0 DEMOB WHDBO NUND T Blow down CT and Rig with N2 20:30 21:30 1.00 0 0 DEMOB WHDBO NUND T Set BPV 21:30 00:00 2.50 0 0 DEMOB WHDBO CTOP T Unstab CT 06/20/2012 Completed reel swap RDMO 00:00 01:30 1.50 0 0 DEMOB WHDBO CTOP T RD inner reel iron, Prepare to lift reel out of rig 01:30 03:30 2.00 0 0 DEMOB WHDBO CTOP T Lower reel out of rig 03:30 07:00 3.50 0 0 DEMOB WHDBO CTOP T Install new reel 07:00 10:00 3.00 0 0 DEMOB WHDBO NUND T ND BOP, RD Rig released at 10:00 Page 12 of 12 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 14, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Gamma Ray Correlation: 2M -01 Run Date: 06/10/2012 & 6/13/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -01 Digital Data (LAS), Digital Log file, 3D Viewer 1 CD Rom 50- 103 - 20185 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com // --ft i Date: t E� Signed: 1 1 r/ 02-103 • z►7 o� WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jewelry Log: 2M -01 Run Date: 6/3/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -01 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20185 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com +- Date: 1 {?�Q� \`)— Signed: 111111 tttt �,� Z« - 73 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 29, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey /Tubing Punch: 2M -01 Run Date: 5/26/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -01 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20185 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 103 - 20185 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood adWitiED AUG 0 3 2012 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 7� ( 7 t Signed: Page 1 of 1 • Schwartz, Guy L (DOA) pyj) /9 -/03 From: Schwartz, Guy L (DOA) Sent: Tuesday, June 19, 2012 3:51 PM To: 'Winfree, Michael Alex (Jr.)' Cc: Allsup- Drake, Sharon K; Gantt, Lamar L Subject: RE: 2M -01A Operations Update (Sundry Number 312 -179) (PTD Number 212 -072 and 212 -073) Mike, Thanks for the update. Submit a 407 and leave well in suspended status. Keep_ me posted on the future plans for drilling. The PTD for 2M -01A is valid for 2 yrs and if plans change you can submit a revision to the existing PTD. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office)�� Vl 1 U " 444 -3433 (cell) From: Winfree, Michael Alex (Jr.) [mailto: Michael .A.Winfree @conocophillips.com] Sent: Tuesday, June 19, 2012 3:22 PM To: Schwartz, Guy L (DOA) Cc: Allsup- Drake, Sharon K; Gantt, Lamar L Subject: 2M -01A Operations Update (Sundry Number 312 -179) (PTD Number 212 -072 and 212 -073) Guy, As we discussed on the phone earlier today, we have made a decision to suspend CTD operations on 2M -01. After a failed attempt to exit the 7" casing off of a whipstock set in a cement pilot hole, the pilot hole was re- cemented and an attempt to drill another pilot hole was unsuccessful. With no favorable alternative kick off point, the decision was made to rig down the CTD rig and move off of 2M -01. We are currently evaluating other methods to develop the resource at 2M -01 such as a Rig Workover or a Rotary Sidetrack to set up CTD laterals. All of the work performed to date has been under the approved sundry (312 -179). No operations were performed under the approved permit to drill (212 -072, 212 -073). A 10-407 will be submitted leaving the well suspended. Please let me know if you need any additional information regarding 2M -01 CTD operations. Thanks, -Mike Mike A. Winfree Drilling Engineer 907.265.6820 Direct 907.242 0246 Celt 6/19/2012 • • 1, , t ) ; SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Venhaus CTD Wells Engineer � I CO ConocoPhillips Alaska, Inc. 1 q P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2M -01 Sundry Number: 312 -179 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, a-4 1 Cathy P. Foerster Chair sF DATED this 2 day of May, 2012. Encl. STATE OF ALASKA 4 - 64A- EC E I` E D ' ALIA OIL AND GAS CONSERVATION COM ON MAY 1 1 201 APPLICATION FOR SUNDRY APPROVALS 07s .S/ z 20 AAC 25.280 l^) 1. Type of Request: Abandon r Flug for Redrill • Perforate New Pool r Repair well r Change4T6Vet r Suspend r Rug Perforations P • Perforate r Rill Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 192 - 103 • 3. Address: Stratgraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20185 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No Fy 2M -01 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25585 • 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): 9800 • 6331 • 9697' 6248' Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 117' 117' SURFACE 3305 9.625 3346' 2748' PRODUCTION 9752 7 9785' 6319' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9435' - 9489' 6044' - 6085' 3.5 J - 9374 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FB -1 PACKER MD= 9339 TVD= 5973 SSSV - CAMCO TRDP -4A MD =1819 TVD =1782 12. Attachments: Description Summary of Proposal pa 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory F" Development pi Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2012 Oil r Gas r WDSPL r Suspended p ►v 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned — rte'" S' Commission Representative: GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Venhaus @ 263 -4372 Printed Name Dan Venhau0' Title: CTD Wells Engineer Signature' ��/�✓ yL ,y , -�.-0 �- Phone: 263 -4372 Date .S - i f L7 1 2 v Commission Use Only Sundry Number: 3 z..1.-7 9 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test J' ✓Mechanical Integrity Test r Location Clearance r Ai 3s0° I OSi- eaP I Other: 2.4 AlkC L- S4I2.-(t) 41, AI fe_ex....-- p 1,44, P1 „,...,_,.....,4- " ,r6 ` Subsequent Form Required: / 6 — Y 07 � ` ' LL0 'y �/� APPROVED BY Approved by: F ' _ COMMISSIONER THE COMMISSION Date: v - / _ Form 10 -403 Revis MAY 2 � S�6l Submit i n Du plica te ' � t' S MA 2 201 t �� €1/�/� E KUP • 2M -01 1 Conoc Oi Well Attributes Max Angle & MD TD Alaska Inc Wellborn API /UWI Field Name Well Status Ind (1 MD (ftKB) Act Bern (ftKB) 501032018500 KUPARUK RIVER UNIT PROD 61.81 2,801.74 9,800.0 Canocti Philips — Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date SSSV: TRDP 25 10/28/2011 Last WO: 46.02 10/30/1992 Well Conlin' - 2M0,420/2012236'46 PM Sche m Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,528.0 3/12/2012 Rev Reason: GLV C /O, TAG ninam 4/20/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth ITVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 41.0 117.0 117.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER 38 SURFACE 95/8 8.765 40.5 3,345.7 2,748.9 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.4 9,785.1 6,319.2 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB I 9 ,375.2 ) Set Depth I (f... Set Depth (D) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 I 37.6 5,999.3 N 9.30 I J -55 ABM - eue Completion Details Top Depth (ND) Top Ind Noon ... Top IftKB) (ftKB) (°I Rem Description Comment ID (in) 37.6 37.6 0.03 HANGER FMC GEN IV TUBING HANGER 3.500 1,818.8 1,782.1 23.12 SAFETY VLV CAMCO TRDP -4A SSSV 2.812 9,338.4 5,972.1 42.72 SEAL BAKER GBH -22 SEAL ASSY w /5' EXTRA SPACER TUBE OD 5.0", ID 4.000 CONDUCTOR,_ 41 -117 4'0„ 9,339.2 5,972.7 4272 PACKER BAKER FB -1 PACKER 4.000 9,362.6 5,989.9 42.58 NIPPLE CAMCO D NIPPLE 2.750 v1 9,374.3 5,998.6 42.44 SOS BAKER SHEAR OUT. TTL ELMD @ 9362' SWS LET 11/3/1992 2.992 SAF LTY VLV, B19 Perforations & Slots _ Shot Top (ND) elm (ND) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh..• Type Comment 9,435 9,489 6,043.8 6,084.6 C-4, A -3, 2M -01 12/18/1992 4.0 IPERF 4 1/2" Csg Gun, 180 deg. phasing i Notes: General & Safety I ' End Date Annotation I! 3/8/2011 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE, Al l 40 -3,348 GAS LIFT, r. 3,450 GAS LIFT C 6,839 GAS LIFT —I C' 6 545 GAS Llr 9 119 GAS LIFT :: 9.286 SEAL, 9,338 PACKER, 5,330 T'" I NIPPLE, 9,363 303, 9,374 --_ � ll] Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) 1 ° ) Make Model (in) Serf Type Type (in) (psi) Run Date Com... 1 3,449.8 2,803.4 58.73 CAMCO FMHO 1 GAS LIFT GLV BK 0.156 1,288.0 4/8/2012 9.435.9.489 III 2 6,839.4 4,514.6 60.65 CAMCO FMHO 1 GAS LIFT GLV BTM 0.250 1,434.0 4/8/2012 II 3 8,545.0 5,414.9 50.92 CAMCO FMHO 1 GAS LIFT OV BK 0.250 0.0 4/7/2012 4 9,119.1 5,810.5 42.70 CAMCO FMHO 1 GAS LIFT DMY BK 0.000 0.0 12/18/1992 5 9,286.2 5,933.7 42.62 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/10/2000 PRODUCTION. 1 33 -9.785 1 i TD. 9.600 2M -01 Proposed CTD Sidetrack 3 -1/2" Camco TRDP -4A SSSV @ 1782' MD 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface 16" 62# H -40 shoe @ 117' MD 3 -1/2" Camco FHMO gas lift mandrels @ 3450, 6839, 8545, 9119 9 -5/8" 36# J -55 shoe @ 3346' MD —wow is■- 3 -1/2" Camco MMG -2 gas lift mandrel @ 9286 Baker 3 -1/2" GBH -22 Seal Assy w/ 5'spacer tube @ 9338' MD (4" ID) • Baker FB -1 packer @ 9339' MD (4.0" ID) 3 -1/2" Camco D landing nipple @ 9363' MD (2.75" min ID, No -Go) 2 -3/8" liner top — milled out to 2.80" prior to rig arrival 9370' MD 3 -1/2" tubing tail @ 9374' MD NO NON AU Elk 2.80" pilot hole .. through cement ,Top of Whipstock @ 9435 MD KOP @ 9435' MD i a #� C -sand perfs - 9435' 9489' MD ' ',. (C sand) • 2M -01 AL1 C sand _ TD = 12250' MD Liner top © 9370' MD 2M -01AL1 wp02 3" openhole, A 2 -3/8" slotted liner 2M -01A (A sand) . TD = 12300 MD Alum billet @ 9600' MD 7" 26# J -55 shoe @ - 2M -01A wp05 9785' MD • KRU 2M -01 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well 2M -01 is a Kuparuk A- sand/C -sand production well equipped with 31/2" tubing and 7" production casing. Two proposed A -sand CTD laterals will increase reservoir exposure and probe the western periphery of 2M pad. Prior to drilling, the existing perfs in 2M -01 will be squeezed with cement to provide a means to kick out • of the 7" casing. This will permanently abandon the Kuparuk A -sand and C -sand perfs in well KRU 2M -01. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the perfs in this manner. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 9485' MD • and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2M-01A _ sidetrack will exit the 7" casing at 9435' MD and will target the A3 sand west of the existing well with a 2865' • lateral. The hole will be completed with a 2 slotted liner to the TD of 12,300' MD with an aluminum billet at 9600' MD. The 2M -01AL1 lateral will kick off from the aluminum billet at 9600' MD and will target the C4 sand west of the existing well with a 2650' lateral. The hole will be completed with a 2 slotted liner to the TD of 12,250' MD with the final liner top located just inside the 31/2" tubing at 9370' MD. CTD Drill and Complete 2M -01 Laterals: July 2012 Pre -CTD Work 1. RU slickline. Tag fill. Get updated static BHP survey. 2. RU e -line. Perf holes in 31/2" tubing tail at 9357' MD. RD e-line. 3. RU coil. Mill out D- nipples at 9362' to 2.80" ID. 4. RU coil. Plug all perfs with cement from —9558' up to the tubing tail perfs at 9357' MD. RD . coil. 5. RU slickline. Tag top of cement. RD slickline. — ' � , : `13S 7- 776 1124 6. Prep site for Nabors CDR2 -AC, including setting BPV . 0 373 136E - 4i' Rig Work G 4 edi-s 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 2M -01A Sidetrack (A3 sand, west) 6A a. Drill 2.80" high -side pilot hole through cement to 9485' MD'. 311.-175 b. Drift pilot hole with whipstock dummy c. Set whi. stock at 9435' MD wit i . . 4 - ' • - 611 . • 1 d. Mill 2.80" window at 9435' MD. e. Drill 2.70" x 3" bi- center lateral to TD of 12,300' MD W Nu•► f. Run 21/2" slotted liner with an aluminum billet from TD up to 9600' i t/ /' larel�►l recPr; II wt 11 e�'t- - - eX� YT� J' weli 7 J� 4 i Ile mew 4- k c'or /errs Gf' �n obi ifo/ CdM /kl o �`f' U'''rh The 6//1011 �er►�rDhl �° F /off l «er AKA 70 ;IIj'dr e'triffi%1� u4l/,( 74 7:.1 Ca (94 q'toe) ' / / 1r e i fea v v el, r 1 i 1$ 7r /feh, �/b old o fvc4 wvvlq ery 5 nM at l! Cvr(eN,4 lo caA'1 / 3prvf) !C'C0�"fs co „ /t'f F�Ma' f' ll' � C �P /V Page 1 of 2 (', ! f miCetz y• May 10, 2012 FINAL • • 3. 2M -01AL1 Lateral (C4 sand, west) a. Kick off of the aluminum billet at 9600' MD b. Drill 2.70" x 3" bi- center lateral to TD of 12,250' MD c. Run 2 slotted liner from TD up to 9370' MD, up inside the 31/2" tubing tail 4. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Put well on production II I, Page 2 of 2 May 10, 2012 FINAL • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art / or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 �/ form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). , 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and ►/ operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill" 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 \°12.03 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 18, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAY 2 3 1012. RE: Multifinger Imaging Tool (MIT) : 2M -01 Run Date: 4/14/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -01 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20185 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 5�� '� Signed: 14444.4 t � 2_\ c. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 16, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 &LAMED MAY 23 2012 RE: Multifinger Imaging Tool (MIT) / Borehole Pressure Survey (BHPS): 2M -01 Run Date: 3/14/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -01 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50 -103- 20185 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: `: j 1/1-- k 2-. Signed: L / _ ,/ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2008 • RECEIVED JAN ~ $ Z00~ 1Uaaka Oil & Gaa Cora, Camrnlr~ion Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission ~., ~©`~ 333 West 7~` Avenue, Suite 100 ~~~~~~~, ~~~ ~ ~ ~~~~ ~~ Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIS. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ,~ Perry 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 n~*o 01/20/06 Schlumberger NO. 3663 Schlumberger -DCS RECE\VED 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Helen Warman ATTN: Beth JAN 2 4 Z006 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~OA&Gascoos.~ Field: Kuparuk ~ Well Job # Log Description Date BL Color CD ~ 1 E-03 11144062 PROD PROFILE W/DEFT 01/14/06 1 1 F-14 11144063 PRODUCTION PROFILE 01/15/06 1 28-14 11141241 PRODUCTION PROFILE 12/31/05 1 2G-14 11166751 SBHP SURVEY 01/12/06 1 1 E-06 11154118 PROD PROFILE W/DEFT 01/11/06 1 2X-05 11141246 INJECTION PROFILE 01/05/06 1 3A-04 11166752 INJ PROFILEIWFL 01/13/06 1 38-05 11154115 INJECTION PROFILE 01/09/06 1 2X-18 11154114 SBHP SURVEY 01/08/06 1 2X-18 11154117 PROD PROFILE W/DEFT 01/10/06 1 2H-09 11154103 PROD PROFILE W/DEFT 12/29/05 1 1G-11 11154113 PROD PROFILE WIDEFT 01/07/06 1 2X-04 11141245 INJECTION PROFILE 01/04/06 1 2Z-13 11141242 PROD PROFILE W/DEFT 01/01/06 1 1 C-20 11133212 SCMT 12/25/05 1 2C-11 11144065 PROD PROFILE W/DEFT 01/17/06 1 1 ~/ 2N-339 N/A BHP SURVEY 12/01/05 20-04 N/A BHP SURVEY 12/03/05 1 2U-13 11166753 PROD PROFILE W/DEFT 01/14/06 1 1 E-05 11166747 PROD PROFILE W/DEFT 12/25/05 1 2M-01 Ie¡ fj.-/Qþ 11154119 PROD PROFILE W/DEFT 01/19/06 1 SIGNED: SCANNED JAN 3 1 2006 DATE: ~~o 'd ') Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate X Plugging _ Perforate Pull tubing Alter casing _ Repair well _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development X RKB 147 feet 3. Address Exploratory 7. Unit or Property name P. O. Box 100360 Stratigraphic Anchorage, AK 99510-0360 Service Kuparuk Unit 4. Location of well at surface 8. Well number 114' FSL, 19' FWL, Sec. 27, T11N, R8E, UM (asp's487858, 5948986) 2M-01 At top of productive interval 9. Permit number / approval number 1099' FSL, 1096' FEL, Sec. 29, T1 ON, R8E, UM (asp's 481462, 5949984) 192-103 At effective depth 10. APl number 50-103-20185 At total depth 11. Field / Pool 1147' FSL, 1315' FEL, Sec.29, T11 N, R8E, UM (asp's 481237, 5950033) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9800 feet Plugs (measured) Tagged Fill (6/1/00) @ 9442' MD. true vertical 6331 feet Effective depth: measured 9442 feet Junk (measured) true vertical 6049 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 225 Sx PFC 121' 121' SURF CASING 31 99' 9-5/8" 564 Sx Perm E & 600 Sx 3346' 2749' Class G PROD CASING 9638' 7" 198 Sx Class G 9785' 6319' Perforation depth: measured 9435 - 9489' true vertical 6044 - 6085' ' i' ' ! i ; ~ :' '"'!::~":'; )h' ~', ~ ,,',...... . Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55, Tubing @ 9375' MD. Packers & SSSV (type & measured depth) BAKER 'FB-I' PACKER @ 9339' MD. CAMCO 'TRDP-4A'. 2/10/00 - SET FRAC SLEEVE (65" TOTAL LENGTH) 2.31 ID. @ 1819' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 552 456 227 229 Subsequent to operation 981 1016 296 227 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date ¥//~? Signed ///~~..'.. ~ Title: Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE'"'--,. 2M-01 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 2/22/00: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforation interval at: 9435 - 9489' MD Pumped Breakdown stage: a) Pre-Pad stage @ 30 bpm, followed by b) Shutdown. ISIP @ 1732. Resumed pumping Scour stage: c) Gelled Scour stage w/lppa proppant @ 25 bpm, followed by d) Shutdown. ISIP @ 1680. Resumed pumping: e) Gelled Data Frac stage, followed by f) Shutdown. ISIP @ 1849. Resumed pumping Frac Treatment: g) 200 bbls Crosslinked Pad stage @ 22 bpm, followed by h) Crosslinked Slurry stages w/proppant ramped up in stages from 1 to 12 ppa, followed by i) Flush stage, followed by j) Shutdown. Placed 124,421 lbs of proppant into the formation. RD. 2/24/00: RIH w/CT & jetted a proppant fill cleanout to 9655' MD. 2/25100: RIH & tagged fill at 9625' MD. 6/1/00: RIH & tagged fill at 9442' MD. 7/11/00: RIH w/CT & jetted a fill cleanout to 9658' MD. Returned well to production w/gas lift & obtained a valid well test. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E E P L ~A E W M A T E R IA L U N D ER TH IS M A R K ER C:LORBMFILM.DOC Date KUPARUK FLUID LEVEL REPORT CC' DS Engr. NSK Files OP Engrg. Files Prod. Foreman Fluid Level Shot Down: sssv I~l~ ~ · GLM DV or GLV e/l ~/ Casing Tubing CSG Press During Shot =__ # TBG Press During Shot= /4.~"~# Reason For Shooting FL: -- To Determine Operating Valve Well Status: On Continuous GL Operating CSG Press= ~ # GL Rate (If Available) MCFD On Intermittent GL On Time=~ Min. Off Time = Hr. Min. ,, Delta Time From End Of On-Cycle V/' No GL Comments: Min. Ann~,n Individual Well GeOlogical Materials Inventory PERMIT DATA T DATA_PLUS Page' Date- 11/16/94 RUN DATE_RECVD 92-103 5569 92-103 5469 92-103 SURVEY 92-103 SURVEY 92-103 DAILY WELL OP T 9800-3271 OH/CDR/HLDT/CNT 1-2 T 9800-3271 OH/CDR/HLDT/CNT 1-2 R 0.00-9000 GCT 92-103 407 R 0.00-9000 GCT R 10/22-12/1992 R COMP DATE' 12/19/92 92-103 CET L 8700-9888 1 92-103 CDR-DC L 3347-9800 COMP 92-103 CDR L 3300-9800 COMP 92-1103 CBT L 8700-9670 04/02/93 12/07/92 12/07/94 01/13/93 01/13/93 01/13/93 11/16/92 05/14/93 11/10/92 11/16/92 Are dry ditch sam%es~r~? yes no And received? yes no Was the wel. 1 core~ ye Analysis & description received? Are well tests re.Ii?ed'.~ ~/'22 no Received? yes nc.) yes no Well is in compliance Initial ARCO Alaska, lnc. .: :: i.~ ?i~;~-~ ..~-: ! January 11, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ¢I?~ -"' P~, 2M-01 Stimulate ~¢?..--.. ;~ ';; 2M-05 Stimulate "-':~.~.-.~ ~.-~t 2M-08 Stimulate ?.,--~;-:~2M-12 Stimulate ,~;;??i 2M-27 Stimulate q v_ ~.-,-?::~, 2M-28 Stimulate ~,~.~;:. :~ ~,~;.fi, 2M-32 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering STATE OF ALASKA ALAur,,^ OIL AND GAS CONSERVATION COMMIS, _ N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown Stimulate X Pull tubing Alter casing Repair wel 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 114' FSL, 19' FWL, SEC27, T11N, R8E, UM At top of productive interval 1099' FSL, 1096' FEL, SEC 29, T11N, R8E, UM At effective depth At total depth 1147' FSL, 1315' FEL, SEC 29, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 9800' 9697' feet Plugs (measured) feet Plugging Perforate _ Other 6. Datum elevation (DF or KB) 147' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-01 9. Permit number/approval number 10. APl number 50-103-20185 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured true vertical Length 121' 3346' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9785' 7" measured 9435' 9489' true vertical 6044' 6085' 6331 ' 6248' Size 16" 9 5/8" feet Junk (measured) feet Cemented 225 pf "C" 564 SX PERME 3346' 600 SX G 198 SX CLASS G CMT 9 7 8 5' Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55 @ 9375' Packers and SSSV (type and measured depth) Baker F-1 @ 9339', Camco TRDP-4A-MOD @ 1819' Measured depth True vertical depth 121' 121' 2749' 6319' 13. Stimulation or cement squeeze summary Intervals treated (measured) Refer to attached summary Treatment description including volumes used and final pressure 14. Pressure Representative Daily Average Production or Injectj0n Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Prior to well operation Subsequent to operation (Stabilized) 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 1082 1439 14 1240 psi 240 psi 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. Si,ned¢~ (~'' ~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICA-f E April 8, 1993 2M-O1 GSW DATAFRAC W/DOWELL. PUMP 3 SLK WTR PI/SI'S & GSW MINIFRAC @ 25 BPM. DATA AS FOLLOWS: STEP VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC PI/SI%I 150 4619 1670 3700 .71 1074 PI/SI#2 50 4450 1606 3800 .70 969 PI/SI#3 10 4715 1616 3725 .71 1224 MINIFRAC 300 4445 1666 3850 .70 763 FE=47% (SMART CLOS TIME), 43% (DOWELL), BASED ON 45% AVERAGE FE AND ENGINEERS PROC, DECREASED PAD FROM 195 BBLS TO 175 BBLS. GSW REFRAC W/DOWELL. PUMP 175 BBL PAD @ 25 BPM, LAST WHTP=4900 PSI. PUMPED 21.0 MLBS 16/20 CL IN 1-2 PPA STAGES & 76.5 MLBS 12/18 CL IN 4-10 PPA STAGES @ 25 BPM, WHTP INCREASED F/4900 PSI TO 6650 PSI THROUGH OUT PROPPANT STAGES BEFORE SCREENING OUT INST IN 10 PPA STAGE WITH A MAX TRT PRESS OF 8200 PSI. TOT PROP: DESIGN=150.7 MLBS, IN FORM=75.7 MLBS W/7.3 PPA @ PERFS. TOT FLUIDS: WATER=1368 BBL, DSL(FLA + FLUSH)=25 BBL, ADD'S=20 BBL. ALL FLUIDS LOOKED EXCELLENT. SMART COMPUTER WORKED GOOD. (TOTH/ANGLEN) ARCO Alaska, inc. Date: May 07, 1993 Transmittal #: 8732 RETURN TO: ARCO Alaska, Inc. Attn: NikkJ Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the folloWing Open hole items. acknowledge receipt and return one signed copy of this transmittal. Please ~ ~/11~ H- 16 H-16 ~'~_,~ H-19 H-19 H-17 ~f~~ M-01 ~--3.U.--2 M- 12 ?'~-_ ~ ~ 2M-04 ~ _~_2.~ M-14 cf~a-08 c~~ ~/2_ a-02 -'~'"~-"--"~ M-02 CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth Corrected 1/8-10/93 2671-7510 Corrected 1/8-10/93 2671-7510 Corrected 12/13-16/92 5364-8990 Corrected 12/13-16/92 5364-8990 Corrected 1/2-5/93 4981-8185 Corrected 1/2-5/93 4981-8185 Corrected 10/25-29/92 3347-9800 Corrected 9/6-8/92 2801-4766 Corrected 9/23-26/92 4260-12370 Corrected 7/14-17/92 3664-9811 Corrected 11/3-7/92 4253-12151 Corrected 8/31 to 9/3/923437-10003 Corrected 8/31 to 9/3/923437-10003 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Date' R~r~,/I/r-~ -- v£u MA y 7 4 199,~ Ala~l~ 011 & Gas Cons. Commission Anchorage Vendo~ackage(Johnston) NSK State of Alaska(+Sepia) Kathy Worley(Geology) ARCO Alaska, Inc. Date: April 2, 1993 Transmittal #: 8701 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signe.d~opy of this transmittal. -.1 H- 1 6 ¢-~E--~ LIS Tape and Listing -1H-17~ ..'1 H-1 5 S5'7~ -..1 H-20 ~c-~'77.. -1H-01 Please acknowledge receipt and return 01-10-93 CDR/CDN & Enhanced Resolution CDR LIS Tape and Listing 01 - 1 5 - 9 3 CDR/CDN In 2 Bit Run LIS Tape and Usting 0 2 - 2 0 - 9 3 CDR/CDN In 2 Bit Runs. 1 Mad-Pass & Resistivity LIS Tape and Listing 1 2 - 2 7,- 9 2 CDR/CDN In 3 Bit Runs. Phasor Enhanced S~"7~LIS Tape and Listing 01 - 2 9 - 9 3 tCDR/CDN In 2 Bit Runs/Enhanced Resistivity c[-~...O~------1 H -02~~ LIS Tape and Listing 0 2 - 0 5 - 93 CDR/CDN & QRO Enhanced Resistivty LIS Tape and Listing 0 9 - 2 6 - 9 2 CDR Data from Bit Runs 1 & 2/HLDT/LDWG Format LIS Tape and Listing 0 8 - 1 8 - 9 2 CDR/CDN 1 Bit Run in LDWG Format & HLDT Data LIS Tape and Listing 1 0 - 2 9 - 9 2 CDR Bit Runs I & 2/Hi Resolution CDR Processed HLDT & 3 Passes CNTG c~?...-ct"5 -2M-04 ~'-~S"/t ~2.-~ .,- 2M-09 ~ 93013 93007 93038 92735 93O45 93056 92586 92511 92640 Receipt Acknowledged' - ............................ Date: .......... DISTRIBUTION: Bob Ocanas State of Alaska RECEIVED APR 0 2 199~ Alaska 0il & 6as 0ohs. 6ommission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS r~ SUSPENDED r--] ABANDONED 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 92-103 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20185 4 Location of well at sudace 9 Unit or Lease Name 114' FSL, 19' FWL, SEC 27, T11 N, R8E, UM At Top Producing Interval //~_ ~. ~L ..... ,i~i~.~ ~ 10 Well Number ~'~ ~ r~"-~~ 2M-O1 1099' FSL, 1096' EEL, SEC 29, T11N, R8E, OM 1147' FSL, 1315' FEL, SEC 29, T11N, R8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Sedal No. KUPARUK RIVER RKB 147', PAD 106'I ADL: 25585 ALK: 2671 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 21-0cto92 27-0ct-92 12/18/92.J NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 9800' MD, 6331'TVD 9697' MD, 6248' TVD YES [~] NO ~I 1819' feet MDI 1400 APPROX 22 Type Electric or Other Logs Run CDR, CDN, GR, CE-T, CBT, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD 16" 62.5# H-40 SURF 121' 24" 225 PF "C" 9.625" 47#/36# L-80/J-55 SURF 3346' 12.25" 564 SX PERME, 600 SX G 7" 26~ J-55 SURF 9785' 8.5 1198 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MDI 3-1/2" 9.3# J-55 9375' 9339' 9435'-9489' @ 4SPF MD 6044'-6085' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit In duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC ~ FORMATION 3ESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9436' 6045' KUPARUK C BASE 9472' 6072' KUPARUK A TOP 9472' 6072' KUPARUK A BASE 9580' 6155' ._ - · · , . 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measuremenl~s 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 cement.. lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-01 NORTH SLOPE 50-103-20185 ACCEPT: 10/21/92 06:30 SPUD: 10/21/92 11:00 RELEASE: 12/18/92 01:30 OPERATION: DRLGRIG: PARKER 245 WO/C RIG: NORDIC I 10/22/92 (1) TD: 750'( 0) 10/23/92 (2) TD: 3405'(2655) 10/24/92 (3) TD: 3362'( 0) 10/25/92 (4) TD: 3362' ( 0) SPERRY SUN SURVEY MW: 9.1 VIS: 87 MVED RIG F/2M-29 TO 2M-01. ACCEPTED RIG @ 18:30 HRS 10/21/92. NU DIVERTER SYSTEM. FUNCTION TEST DIVERTER BAG & VALVES. FILL STACK & CHECK FOR LEAKS. TIGHTEN GRAY LOCK CLAMP-HOOK UP DIVERTER LINES. DIVERTER & BOP TEST WITNESSED BY LOU GRIMALDI. PU BIT & BHA-ORIENT TOOLS. SPUD WELL @ 23:00 HRS-DRLG 12-1/4" HOLE F/120'-750'. SPERRY SUN SURVEY CBU & COND MUD 9-5/8"@ 3345' MW: 9.6 VIS: 60 DRLG 12.25" HOLE F/743'-834'. SPERRY SUN SURVEY. DRLG 12.25" HOLE F/834'-924'. MWD. NO TOOL FACE. DRLG 12.25" HOLE F/924'-3405'. CBU & COND MUD. SHORT TRIP TO HWDP 9-5/8"@ 3345' MW: 9.8 VIS: 78 CBU @ 3405' & PMP PILL. TRIP OUT TO HWDP. TIGHT F/2000' TO 1600'. TRIP IN. WASH & REAM F/1600' TO 1850'. TAKE SURVEYS. SET TOOL FACE HIGH SIDE & DRILL TO 1960'-HOLE SIDE-TRACKED. POH-CHANGE BIT-CHECK MOTOR & MWD-OK. RIH TO 1960'. DRLG 12-1/4" HOLE F/1960'-3362'. CBU @ 3362'. PMP DRY JOB. TRIP OUT TO HWDP. SET WEAR BUSHING 9-5/8"@ 3345' MW: 8.6 VIS: 30 FIN SHORT TRIP TO HWDP & TRIP BACK IN. CBU @ 3362'-CIRC HOLE CLEAN-PMP PILL. POOH-TIGHT 1730'-1600'. WORK OUT TIGHT SPOTS. LD 8" DC'S & BHA FOR INSPECTION. RU TO RUN 9-5/8" CSG. RIH W/ 78 JTS 47# L-80, 2 JTS 36# J-55, HGR, & LANDING JT-SHOE DEPTH @ 3346'. RU HOWCO & PMP CMT(564 SX PF E CMT & 600 SX CLASS G.). BUMP PLUG, PRESS TO 2000 PSI. HOLD 2000 PSI 10 MIN & CHECK FLOATS-OK. ND DIVERTER, CLEAN OUT CMT F/VALVES & BAG. LD CSG TOOLS. INSTALL SPEED HEAD. NU BOP'S-CHANGE OUT RISER. NU BOP'S. TEST ALL BOP EQUIPMENT @ 300 & 3000 PSI-OK. KOOMY TEST-START 2900 PSI-1775 PSI AFTER CLOSING-200 PSI BUILD UP IN 38 SEC-2 MIN 51 SEC FULL BUILD UP TO 2950 PSI. TEST CHOKE MANIFOLD. BLOW ND & WINTERIZE. BOPE TEST WAIVED BY AOGGC. SET WEAR BUSHING-LD TEST TOOLS-LINE F/CHOKE TO SHAKER'S FROZE. REPLACE 3/8" HOSE STANDPIPE TO SUPER CHOKE GAUGE-WINTERIZE ALL LINES. WELL : 2M-01 OPERATION: RIG : PARKER 245 PAGE: 2 10/26/92 (5) TD: 7845'(4483) 10/27/92 (6) TD: 9243'(1398) 10/28/92 (7) TD: 9800' ( 557) 10/29/92 (8) TD: 9800' ( 0) DRILL & SURVEY 9-5/8"@ 3345' MW: 9.2 VIS: 33 CUT DRLG LINE. REPLACE SPINNER IN IRON ROUGH-NECK. PICK UP BHA-ORIENT-PROGRAM & SURF TEST MWD-TRIP IN HOLE. CIRC OUT THICK MUD HIT PLUG @ 3254' DRILL PLUGS, FLOAT & CMT TO 3290'. CI~C 15 MIN-TEST 9-5/~" CSG TO 2000 PSI. DRILL CMT F/3290'-3362' ~ 10' NEW HOLE TO 3372' CIRC FOR FIT @ 3372'. FIT @ 3372 MD & 2756' TVD, 12.5 ~G EMW W/520 PSI & 8.9 PPG MUD-OK. DRLG 8.5" HOLE F/3372'-7845'. MIXING LC MATERIAL 9-5/8"@ 3345' MW:10.1 VIS: 38 DRLG 8.5" HOLE F/7845'-8035'. REPAIR ACTUATOR IBOP ON TOP DRIVE. DRLG 8.5" HOLE F/8035'-9239'. LOSING FLUID. CIRC & BUILD MUD VOLUME F/POH. POH SLOWLY & CHECK HOLE @ SHOE. DN LOAD LWD INFO & LD BHA & TURBINE. PU NEW BRA-CHANGE OUT JARS-TIH SLOWLY. FILL PIPE & CIRC SLOW-CHECK RETURNS-OK. DRLG F/9239'-9243'. BEGAN LOSING FLUID ONCE DRILLING STARTED. TOTAL FLUID LOST F/05:30-06:00 HRS=200 BBLS. BEGIN MIXING LOST CIRC MATERIAL. START CBU 9-5/8"@ 3345' MW:10.1 VIS: 45 CIRC LCM PILL DOWN @ 2.5 BPM. GOT PARTIAL RETURNS @ 360 BBL PUMPED, FULL RETURNS @ 470 BBL. INCREASE PUMP RATE TO 5 BPM. WATER BACK TO 9.8 PPG & CIRC AROUND. HOLE GIVING SOME MUD BACK. DRILL F/9243'-9350'. ADD LCM TO 10 PPG, BYPASSING SHAKERS. CIRC & WT UP MUT TO 10.1 PPG. DRILL F/9350' TO TD @ 9800'. MONITOR WELL. HOLE STILL GIVING BACK FLUID @ ABOUT SAME RATE AS INITIAL FLOW. CBU, NO SIGN OF GAS. PMP PILL. SHORT TRIP 15 STDS. MONITOR WELL BEFORE RUNNING BACK IN, RATE FLOWING BACK DROPPED. WORK THROUGH TIGHT SPOT F/9500'-9520' GOING IN. POOH TO RUN 7" CSG 7"@ 9785' MW:10.2 VIS: 41 CIRC & COND MUD. MUD BRIEFLY GAS-CUT TO 9.4 PPG F/10.i, SMALL FLOW. UP MUD WT TO 10.2 PPG & CIRC AROUND. DROP SINGLE-SHOT SURVEY. PMP PILL. POOH. TRIP SMOOTH, VERY LITTLE DRAG @ BEGINNING. LOST 2 BBL ON TRIP. RETRV SURVEY. LD BIT(SEALS FAILED). PU LWD, MWD, NEW BIT. PROGRAM TOOLS. RIH. SURF TEST MWD. RIH TO 3326'. SLIP & CUT DRLG LINE. CONT STAGING IN HOLE, FILLING PIPE @ 3326', 5326', 7291', 9120'. MAD PASS W/LWD F/9175'-9800'. SURVEY W/MWD @ 9460' & @ 9800'. POOH TO 9400'. TIGHT F/9553'-9430'. REAL-TIME LOG ACROSS KUP F/9460'9580'. MWD FAILURE @ 9580'(TURBINE BLADES PLUGGED W/LCM) ATTEMPT TO CLEAR W/O SUCCESS. CONTINUE WASHING TO 9800'. CIRC & COND MUD WHILE WORKING PIPE & BTM OF HOLE, NO MUD LOSS. PMP PILL & BEGIN POOH. WORK THROUGH TIGHT SPOTS. WELL : 2M-01 OPERATION: RIG : PARKER 245 PAGE: 3 10/30/92 (9) TD: 9800' ( 0) 10/31/92 (10) TD: 9800'( 0) 12/18/92 (12) TD: 9800 PB: 9750 WAIT ON ARCTIC PACK 7"@ 9785' MW:10.2 VIS: 39 CONT POOH. GAINED 15 BBLS DURING TRIP. DOWNLOAD LWD. LD BHA FOR INSPECTION. PULL WEAR BUSHING. RU TO 7" CSG. HOLD SAFETY MEETING. RUN 7" J-55 BTC & AB/MOD CSG. BREAK CIRC SLOW @ 3288 & 6508' & CBU. RIH TO SHOE SETING DEPTH OF 9785' & MONITOR FLOW. LOST 50 BBLS MUD WHILE RUNNING CSG & CIRC, WELL FLOWING BACK SLOWLY. CIRC & COND MUD WHILE RECIPROCATING CSG. PMP 776 BBLS 10.2 MUD @ 5 & 6 BPM. RECEIVED PARTIAL RETURNS @ 5 BPM UNTIL 450 BBL CIRC, THEN FULL RETURNS. INCREASE RATE TO 6 BPM WITH NEARLY FULL RETURNS. CLEAN LCM OUT OF MUD WHILE CIRC. FINISH RU HOWCO & TEST LINES TO 4000 PSI. PMP CEMENT AS PER DETAIL(198 SX CLASS G). DISPLACE WITH 372 BBLS 10.2 PPG BRINE. BMP PLUG TO 3500# & HOLD 15 MIN-OK. FLOATS HELD. RECIPROCATED CSG THROUGHOUT JOB UNTIL CMT ROUNDED SHOE & CSG STUCK. MONITOR FLOW F/ANN. RETURNS CALCULATED @ 1.8 BPM AFTER 30 MIN OF FLOW. SI WELL & MONITOR PRESS WHILE PREPARE FOR ANARCTIC PACK. CLEANING PTIS TO REMOVE RESIDUAL LCM. RELEASED RIG 7"@ 9785' MW:10.2 VIS: 0 CLEAN PIT TO REMOVE RESIDUAL LCM. RUN MUD THROUGH BALL MILL & PMP. MONITOR ANN PRESS. BUILT TO FINAL PRESS OF 110 PSI. RU HALLIBURTON FOR ARCTIC PACK. PMP 428 BBL FW DN ANN W/RIG @ 10 BPM. SWITCH LINES TO HOWCO. PMP 41.7 BBL(240 SX)PERMAFROST "C" CMT SLURRY W/.014 PPS RETARDER, 15.8 PPG, @ 6.5 BPM & 1000 PSI. PMP 46.1 BBL ARCTIC PACK @ 6.5 BPM. MONITOR ANN PRESS, DROPPED TO 0 PSI @ 1600 HRS. FINISH CLEANING PITS & BLOWING DN LINES. OPEN ANN, DRAIN BOP STACK. ARCTIC PACK/CMT SET OK. PICK UP STACK, SET 130K# ON 7" SLIPS. BLOW OUT LANDING JT & CUT W/MECHANICAL CUTTERS. LD LANDING JT & ND BOP. DRESS CSG STUB & INSTALL PACKOFF. NU FMC 11" 3K X 7-1/16" 5K TBG HEAD & TEST PACKOFF TO 3000 PSI-GOOD TEST. RIG RELEASED 24:00 HRS 10/30/92(00:00 10/31/92). RIH W/TBG & JEWELRY 7"@ 9785' MW: 0.0 MOVE RIG F/2M-06 TO 2M-01. RIG ACCEPTED @ 10:00 HRS 12/17/92. LEVEL RIG-ND TREE. NU BOP. TEST ALL BOPE TO 3500 PSI. PULL TEST PLUG. TEST CSG TO 3500 PSI F/30 MIN-LOSE 25 PSI. RU SWS. TEST LUB TO 1000 PSI-RIH @ 13:20 HRS W/GUN ~1 20', 4-1/2", 4 SPF, 180 DEGREE PHASING. PERF F/9469'-9489', OOH @ 15:20 HRS. RIH @ 15:45 HRS W/GUN #2, 20', PERF F/9449;-9469', OOH @ 17:30 HRS-RIH W/GUN #3 @ 18:05 HRS, 14', PERF F/9435'-9449'. POOH. MU JB & 6.0" GAUGE RING, RIH @ 19:30 HRS. MAX DEPTH 9400 FT. MU SETTING TOOL & BAKER F-1 PERM PKR, RIH @ 21:30 HRS, SET PKR @ 9329', POOH, RD SWS. RU FLOW RISER, RU TBG TONGS. MU BAKER SEAL ASSY. RIH W/3-1/2" ASSY. RIH W/3-1/2" COMPLETION ASSY. WELL : 2M-01 OPERATION: RIG : NORDIC 1 PAGE: 4 12/19/92 (13) TD: 9800 PB: 9697 RIG RELEASED 7"@ 9785' MW: 0.0 SERV RIG. CONT RIH W/3-1/2" COMPLETION ASSY. MU SSSV. ATTACH CONTROL LINE & TEST SAME TO 5000 PSI. RIH. TAG PKR. SPACE WELL OUT. MU TBG HGR. ATTACH CONTROL LINE & TEST TO 5000 PSI. LAND TBG. RILDS. PRESS ANN TO 1000 PSI. CLOSE SSSV. BLED TBG TO 500 PSI TO TEST SSSV. TEST TBG TO 2500 PSI. TEST ANN TO 2500 PSI. SHEAR BALL @ 3700 PSI W/2500 PSI ON TBG. LD LJT. SET BPV. ND BOP. NU FMC GEN VI 5000 PSI TREE. PULL BPV. SET TEST PLUG. TEST PACKOFF & TREE TO 5000 PSI. PULL BPV. PMP 12 BBLS DIESEL DN ANN TAKING RETURNS OUT OF TBG. PMP 4 BBLS DIESEL DN TBG @ 1 BPM @ 1900 PSI. SET BPV. SICP=0 SITP=0. RELEASED RIG @ 13:30 HRS 12/18/92. SIGNATURE: DATE: SUB- SURFACE DIRECTIONAL SURVEY [-~'~ UIDANCE )'~ ONTINUOUS ~ OOL Company Well Name ARCO ALASKA, INC. 2)1-01 (114' FSL, 19' FWL, SEC 27, TllN, R8E,UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA. Job Reference No. 92661 Locjcjed BV: SCHWARTZ Date 3-NOV-92 Computed By: KRUWELL * SCHLUMBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 2M-O1 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 3-NOV-g2 ENGINEER - SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION' LINEAR VERTICAL SECTION' HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 79 DEG 41MIN WEST ARCO ALASKA INC. 2M-01 KUPARUK RIVER NORTH SLOPE, ALASKa COMPUTATION DATE: iS-NOV-92 PAGE 1 DATE OF SURVEY: 3-NOV-92 KELLY BUSHING ELEVATION: i47.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN lO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN 0 O0 iO0 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 iooo oo ilOO i200 i300 i400 i500 i600 i700 i800 i900 0 O0 -147 O0 iO0 200 299 399 499 599 699 799 899 O0 -47 O0 O0 53 O0 99 i52 99 97 252 97 9i 352 9i 85 452 85 79 552 79 69 652 69 47 752 47 0 0 0 23 0 33 0 42 i 4i i 57 2 2 2 i2 2 53 4 39 999 Oi O0 1098 O0 li97 O0 i295 O0 i392 O0 1487 O0 i580 O0 1672 O0 1764 O0 i856 852 oi 29 951 i8 i050 27 ii48 i9 1245 42 1340 68 1433 79 1525 86 1617 03 17o9 6 10 29 7 31 18 9 41 27 12 28 19 15 59 42 19 33 68 22 23 79 23 5 86 22 57 03 26 21 DEG MIN N 0 0 E S 54 7W S 61 3i W S 78 4i W N 68 9 W N59 ii W N 54 lOW N 52 56 W N 67 20 W N 81 49 W N 82 48 W N81 lW N 76 26 W N 77 42 W N 80 2W N 79 40 W N 75 48 W N 73 58 W N 74 1 W N 73 59 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 14 0 83 1 69 3 81 6 89 10 05 13 30 17 42 23 95 0 O0 0 63 0 ii 0 81 0 67 0 O0 0 O1 0 98 i 32 1 71 0 O0 N OlOS o 56 s o 95 s o 6o s o 9o N 281 N 5 07 N 7 16 N 8 70 N 0 O0 E O16W 0 95W 189W 3 98 W 6 84 W 9 70 W 12 60 W 16 41 W 22 76 W 0 oo N 0 0 E 0 1 2 4 6 10 13 17 24 19 S 58 26 W 10 S 59 37 W 11 S 63 13 W 03 S 81 28 W 90 N 82 30 W 10 N 73 51 w 58 N 68 5 W 90 N 66 26 W 36 N 69 5 W 33 45 45 40 60 21 79 62 104 15 134 63 170 65 209 40 248 24 289 08 1 28 1 51 3 18 2 38 3 82 4 07 2 97 0 24 0 46 6 13 9 91 N 11 14 18 23 28 36 46 57 68 32.20 W 51N 44.05 W 45 56 N 58.55 W 60 96 N 77.48 W 79 71 N 101 55 W 104 89 N 131 58 W 134 47 N 166 82 W 170 92 N 204 30 W 209 68 N 241 82 W 248 97 N 281 28 W 289 33 69 N 72 53 W 53 N 75 21W 33 N 76 2 W 77 N 76 15 W 28 N 76 51W 71 N 77 37 W 76 N 77 40 W 62 N 77 4 W 6O N 76 35 W 61 N 76 13 W 2000 O0 1943 46 1796 46 31 21 2i00 22OO 2300 2400 2500 2600 27OO 28OO 2900 O0 2027 O0 2107 O0 2183 O0 2253 O0 2318 O0 2377 O0 2431 O0 2479 O0 2527 27 1880 44 1960 45 2036 77 2106 18 2171 49 2230 24 2284 65 2332 27 34 48 44 38 32 45 42 49 77 47 40 18 51 54 49 55 19 24 59 34 65 61 48 40 2380.40 61 10 N 71 28 W N 71 20 W N 72 31W N 73 59 W N 75 20 W N 76 27 W N 77 10 W N 77 47 W N 78 40 W N 78 56 W 1001 337 18 391 11 450 28 514 81 585 58 661 87 742 26 826 49 913 95 8O 2 87 3 52 3 55 4 66 4 78 3 73 3 75 4 40 0 5O 0 62 83 26 N 327 57 W 337 99 N 75 44 W 100 119 138 156 175 193 212 229 246 78 N 379 37 N 435 05 N 498 87 N 566 42 N 640 76 N 719 07 N 8Ol 83 N 887 87 N 973 20 W 392 95 W 452 15 W 516 66 W 587 82 W 664 19 W 744 47 W 829 14 W 916 34 W 1004 36 N 75 7 W O0 N 74 41W 92 N 74 31W 97 N 74 32 W 40 N 74 41W 83 N 74 55 W 06 N 75 ii w 43 N 75 29 W 15 N 75 46 W 3000 O0 2576 03 2429 03 60 40 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2625 O0 2674 O0 2725 O0 2777 O0 2829 O0 2881 O0 2932 O0 2984 O0 3036 32 2478 91 2527 46 2578 45 2630 41 2682 26 2734 96 2785 73 2837 59 2889 32 60 20 91 60 1 46 59 12 45 58 29 41 58 47 26 58 46 96 58 58 73 58 48 59 58 43 N 79 iS W 1089 18 N 79 28 W 1176 19 N 79 41W 1263 02 N 80 12 W 1349 30 N 80 38 W 1434 72 N 80 36 W 1520 N 8O 32 W 1605 N 80 22 W 1691 N 80 31W 1776 N 80 28 W 1862 15 65 24 79 28 0 67 0 23 1 22 1 20 0 40 0 29 0 45 0 34 0 13 0 54 263 44 N 1059 13 W 1091 40 N 76 2 W 279 295 310 324 338 352 366 38O 394 45 N 1144 26 N 1230 26 N 1315 45 N 1399 41N 1483 45 N 1567 66 N 1652 83 N 1736 97 N 1820 65 W 1178 04 W 1264 01W 1351 24 W 1436 53 W 1521 88 W 1607 29 W 1692 67 W 1777 99 W 1863 27 N 76 17 W 98 N 76 30 W 11 N 76 43 W 37 N 76 57 W 64 N 77 9 W 01 N 77 20 W 48 N 77 29 W 93 N 77 38 W 33 N 77 46 W ARCO ALASKA INC. 2M-O1 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18-NOV-92 PAGE 2 DATE OF SURVEY: 3-NOV-92 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 1-RUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3088,42 2941 42 58 49 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3140 18 2993 O0 3192 07 3045 O0 3243 83 3096 O0 3295 54 3148 O0 3347 31 3200 O0 3398 95 3251 O0 3450.40 3303 O0 3501.73 3354 O0 3553.06 3406 18 58 48 07 58 45 83 58 51 54 58 54 31 58 49 95 58 58 4O 59 5 73 59 8 06 59 7 N 80 22 W 1947 79 N 80 14 W 2033 N 80 14 W 2118 N 80 6 W 2204 N 80 3 W 2289 N 80 0 W 2375 N 79 49 W 2461 N 79 42 W 2546 N 79 32 W 2632 N 79 28 W 2718 35 83 39 98 54 17 92 74 56 0 19 0 16 0 33 0 5O 0 54 0 21 0 O8 0 23 0 12 0 O7 409.21 N 1905 32 W 1948 76 N 77 53 W 423.65 N 1989 438.20 N 2073 452.81N 2158 467.58 N 2242 482.39 N 2326 497.43 N 2411 512.68 N 2495 528.15 N 2579 543.80 N 2664 65 W 2034 89 W 2119 20 W 2205 50 W 2290 77 W 2376 07 W 2461 46 W 2547 87 W 2633 25 W 2719 26 N 77 59 W 68 N 78 4 W 19 N 78 9 W 73 N 78 13 W 25 N 78 17 W 85 N 78 21W 58 N 78 23 W 37 N 78 26 W 18 N 78 28 W 5000 O0 3604 31 3457 31 59 16 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3655 O0 3706 O0 3756 O0 3807 O0 3857 O0 3906 O0 3956 O0 4005 O0 4054 35 3508 25 3559 81 3609 06 3660 08 3710 88 3759 44 3809 72 3858 79 3907 35 59 21 25 59 29 81 59 47 06 59 51 08 60 4 88 60 12 44 60 18 72 60 36 79 60 40 N 79 21W 2804 43 N 79 9 W 2890 N 79 14 W 2976 N 81 39 W 3062 N 81 56 W 3149 N 82 5 W 3235 N 82 14 W 3322 N 82 8 W 3409 N 81 57 W 3496 N 81 56 W 3583 42 49 75 15 67 3O 08 O2 08 0 29 0 12 0 96 0 67 0 26 0 64 0 59 0 26 0 20 0 34 559.61N 2748 65 W 2805 04 N 78 30 W 575.63 N 2833 591.89 N 2917 606.09 N 3002 618.39 N 3088 630.46 N 3174 642.28 N 3259 654.06 N 3346 666.13 N 3432 678.39 N 3518 14 W 2891 67 W 2977 76 W 3063 33 W 3149 08 W 3236 99 W 3322 04 W 3409 21W 3496 48 W 3583 03 N 78 31W 10 N 78 32 W 32 N 78 35 W 64 N 78 41W 09 N 78 46 W 66 N 78 51W 37 N 78 56 W 26 N 79 1W 28 N 79 5 W 6000 O0 4103 73 3956 73 60 43 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4152 O0 4201 O0 4250 O0 4299 O0 4348 O0 4397 O0 4446 O0 4495 O0 4544 58 4005 39 4054 15 4103 10 4152 10 4201 13 4250 36 4299 32 4348 45 4397 58 60 41 39 60 56 15 60 43 10 60 39 10 60 41 13 60 32 36 60 34 32 60 43 45 60 23 N 81 52 W 3670 23 N 81 51 W 3757 43 N 81 52 W 3844 64 N 81 56 W 3931 88 N 81 58 W 4019 02 N 81 46 W 4106 12 N 81 34 W 4193.23 N 81 22 W 4280.23 N 82 18 W 4367.36 N 82 14 W 4454,38 0 63 0 76 0 39 0 47 0 38 0 45 0 31 0 37 0 36 0 50 690 67 N 3604 82 W 3670 39 N 79 9 W 703 715 727 740 752 764 777 790 802 08 N 3691 46 N 3777 76 N 3864 O0 N 3950 33 N 4036 96 N 4122 91N 4208 32 N 4295 05 N 4381 19 W 3757 55 N 79 13 W $9 W 3844 74 N 79 17 W 02 W 3931 96 N 79 20 W 36 W 4019 07 N 79 23 W 65 W 4106 16 N 79 27 W 89 W 4193 25 N 79 29 W 96 W 4280 24 N 79 32 W 27 W 4367.37 N 79 34 W 57 W 4454.38 N 79 38 W 7000 O0 4593 82 4446 82 60 27 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 4643 O0 4692 O0 4741 O0 4790 O0 4840 O0 4892 O0 4944 oo 4998 15 4496 57 4545 61 4594 81 4643 85 4693 O1 4745 67 4797 73 4851 O0 5053.41 4906 15 60 28 57 60 29 61 60 41 81 60 14 85 59 31 O1 59 2 67 57 33 73 57 9 41 56 42 N 82 7 W 4541 26 N 82 4 W 4628 N 82 9 W 4715 N 82 16 W 4802 N 82 57 W 4889 N 83 25 W 4975 N 83 54 W 5061 N 85 32 W 5145 N 86 41W 5229 N 87 12 W 5312 17 O3 O9 O4 46 18 86 45 5O 0 64 0 67 0 16 0 21 1 32 1 24 1 31 2 21 0 51 0 44 813 88 N 4467 73 W 4541 26 N 79 41 W 825 837 849 86O 871 88O 888 894 898 88 N 4553 83 N 4639 72 N 4726 96 N 4812 23 N 4898 80 N 4984 64 N 5068 24 N 5152 70 N 5236 88 W 4628 99 W 4715 33 W 4802 66 W 4889 62 W 4975 O1W 5061 66 W 5145 59 W 5229 2O W 5312 17 N 79 43 W 03 N 79 46 W 10 N 79 48 W 06 N 79 51W 50 N 79 55 W 24 N 79 59 W 96 N 8O 3 W 62 N 80 9 W 76 N 80 16 W ARCO ALASKA INC. 2M-O1 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 18-NOV-92 PAGE 3 DATE OF SURVEY: 3-NOV-92 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 8000 O0 5108 18 4961 18 56 53 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5162 O0 5217 O0 5272 O0 5329 O0 5387 O0 5450 O0 5514 O0 5581 O0 5651 74 5015 33 5070 84 5125 O1 5182 22 5240 17 5303 57 5367 05 5434 O0 5504 74 57 1 33 56 49 84 55 44 O1 55 46 22 52 51 17 49 54 57 49 22 05 47 14 O0 44 11 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 87 25 W 5395.43 N 87 0 W 5478 51 N 87 8 W 5561 N 86 16 W 5644 N 86 18 W 5726 N 84 55 W 5807 N 84 35 W 5884 N 84 58 W 5960 N 85 41W 6035 n 85 33 W 6106 0.31 0.28 906 61 0.30 911 16 0.03 915 35 0.87 921 18 2.47 927 55 0.79 934 76 3.94 941 12 4.86 947 15 4.43 952 902 63 N 5319.78 W 5395.81 N 80 22 W 72 N 5403.48 W 5479.03 N 80 28 W O1N 5487.16 W 5562.27 N 80 34 W 79 N 5570 19 W 5644 97 N 80 40 W 17 N 5652 76 W 5727 32 N 80 45 W 17 N 5733 82 W 5808 30 N 80 49 W 27 N 5811 17 W 5885 80 N 80 52 W 27 N 5887 35 W 5962 12 N 80 55 W 56 N 5961 79 W 6036 62 N 80 58 W 74 N 6033 05 W 6107 81 N 81 2 W 9000 O0 5723 55 5576 55 43 23 9100 9200 9300 9400 9500 9600 9700 9800 O0 5796 O0 5870 O0 5943 O0 6017 O0 6092 O0 6170 O0 6250 O0 6331 52 5649 16 5723 91 5796 61 5870 99 5945 55 6023 67 6103 16 6184 52 42 51 16 42 26 91 42 42 61 41 53 99 40 24 55 37 48 67 36 24 16 36 24 N 85 12 W 6174 67 N 85 53 W 6242 N 86 7 W 6309 N 84 53 W 6377 N 81 47 W 6444 N 80 10 W 6510 N 78 25 W 6573 N 75 26 W 6633 N 75 26 W 6692 68 93 10 51 21 31 O1 19 0 80 0 80 0 24 1 55 3 82 1 83 3 17 0 O0 0 O0 958 62 N 6101 62 W 6176 46 N 81 4 W 963 968 973 981 992 1003 1017 1032 89 N 6169 66 N 6237 71N 6304 32 N 6371 05 N 6436 45 N 6498 64 N 6556 56 N 6614 79 W 6244 27 W 6312 62 W 6379 76 W 6446 59 W 6512 65 W 6575 75 W 6635 18 W 6694 63 N 81 7 W 04 N 81 10 W 37 N 81 13 W 89 N 81 15 W 59 N 81 14 W 66 N 81 13 W 25 N 81 11W 30 N 81 8 W COMPUTATION DATE: 18-NOV-92 PAGE 4 ARCO ALASKA INC. 2M-O1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 3-NOV-92 KELLY BUSHING ELEVATION: 147.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 0 01 6 10 46 31 21 03 60 40 42 58 49 31 59 16 73 60 43 82 60 27 18 56 53 55 43 23 ENGINEER: SCHWARTZ VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 -147 O0 O0 999.01 852 O0 1943.46 1796 O0 2576 03 2429 O0 3088 42 2941 O0 3604 31 3457 O0 4103 73 3956 O0 4593 82 4446 O0 5108 18 4961 O0 5723 55 5576 0 O0 45 18 18 79 43 23 26 43 67 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 N 0 0 E N 82 48 W 33 N 71 28 W 337 N 79 15 W 1089 N 8O 22 W 1947 N 79 21W 2804 N 81 52 W 3670 N 82 7 W 4541 N 87 25 W 5395 N 85 12 W 6174 0 O0 1 28 2 87 0 67 0 19 0 29 0 63 0 64 0 31 0 8O 0 O0 N 9 83 263 409 559 690 813 902 958 0 O0 E 91N 32 26 N 327 44 N 1059 21N 1905 61N 2748 67 N 3604 88 N 4467 63 N 5319 62 N 6101 0 O0 N 0 0 E 20 W 33 57 W 337 13 W 1091 32 W 1948 65 W 2805 82 W 3670 73 W 4541 78 W 5395 62 W 6176 69 N 72 53 W 99 N 75 44 W 4O N 76 2 W 76 N 77 53 W 04 N 78 3O W 39 N 79 9 W 26 N 79 41W 81 N 80 22 W 46 N 81 4 W 9800.00 6331.16 6184.16 36 24 N 75 26 W 6692.19 0.00 1032.56 N 6614.18 W 6694.30 N 81 8 W COMPUTATION DATE' 18-NOV-92 PAGE 5 ArCO ALASKA INC. 2M-01 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY KELLY BUSHING ELEVATION ENGINEER 3-NOV-92 147.00 FT SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 147 O0 247 01 347 02 447 06 547 11 647 18 747 25 847 39 947 71 0 O0 -147 O0 147 247 347 447 547 647 747 847 947 O0 0 O0 O0 100 O0 O0 200 O0 O0 300 O0 O0 400 O0 O0 500 O0 O0 600 O0 O0 700 O0 O0 800 O0 0 0 N 0 0 E 0 33 S 60 7 W 0 34 S 64 48 W 1 15 N 83 51W I 52 N 62 14 W 1 57 N 56 11W 2 6 N 51 42 W 2 27 N 6O 48 W 3 43 N 75 59 W 5 28 N 82 42 W 0 O0 0 44 I 2O 2 45 5 22 8 38 11 57 15 07 20.09 28.14 0 O0 0 10 0 O0 1 44 0 50 0 19 0 35 0 87 2 46 1 80 0 O0 N 0 O0 E 30 S 0 76 S 1 97 S 2 02 N 5 76 N 8 83 N 11 10 N 14 O1 N 18 25 N 26 5O W 35 W 66 W 30 W 2O W O6 W 21 W 96 W 92 W 5 8 11 15 2O 28 0 oo N 0 0 E 0 58 S 58 39 W I 55 S 60 40 W 2 83 S 70 0 W 30 N 89 45 W 39 N 77 54 W 71 N 70 55 W 47 N 66 45 W 59 N 67 6 W 46 N 71 2 W 1048 30 1047 O0 1149 1250 1353 1457 1563 1671 1780 1889 2004 18 1147 67 1247 17 1347 32 1447 68 1547 96 1647 60 1747 90 1847 17 1947 900 O0 6 52 O0 1000 O0 8 29 O0 1100 O0 11 22 O0 1200 O0 14 23 O0 1300 O0 17 56 O0 1400 O0 21 33 O0 1500.00 23 6 O0 1600.00 22 55 O0 1700.00 25 45 O0 1800.00 31 28 N 82 34 W 38.94 N 78 1W 52.23 N 76 44 W 69.42 N 78 50 W 91.88 N 80 28 W 120.91 N 77 35 W 157.07 N 73 55 W 198.45 N 74 2 W 240.72 N 74 6 W 284.56 N 71 26 W 339.36 1 26 2 16 2 71 4 03 2 82 2 88 0 23 0 24 6 18 2 92 10 62 N 12 16 21 26 33 43 55 67 83 37 65 W 77 N 50 71N 67 47 N 89 53 N 118 32 N 153 88 N 193 60 N 234 71N 276 97 N 329 39 12 N 74 15 W 77 W 52 52 W 69 48 W 92 07 W 121 59 W 157 73 W 198 55 W 241 92 W 285 66 W 340 35 N 75 53 W 56 N 76 6 W 03 N 76 30 W O1 N 77 20 W 16 N 77 46 W 64 N 77 14 W 05 N 76 40 W 07 N 76 16 W 18 N 75 43 W 2124 17 2047 O0 1900 O0 35 42 2251 2390 2547 2731 294O 3143 3341 3533 3727 25 2147 04 2247 58 2347 72 2447 49 2547 82 2647 76 2747 94 2847 18 2947 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 N 71 31W O0 40 32 N 73 22 W 482 O0 47 12 N 75 11 W 578 O0 53 35 N 76 51 W 699 O0 60 46 N 78 8 W 854 O0 60 57 N 79 2 W 1037 O0 60 20 N 79 29 W 1214 O0 58 39 N 80 26 W 1385 O0 58 47 N 80 34 W 1549 O0 58 52 N 80 27 W 1714 404 93 63 30 67 O1 23 26 O8 17 51 3 64 4 76 4 77 3 20 3 56 0 53 0 20 2 25 0 25 1 12 105 22 N 392 43 W 406 29 N 74 59 W 128 155 184 217 253 286 316 343 370 94 N 467 O0 N 559 17 N 677 81N 828 64 N 1008 42 N 1182 30 N 1350 16 N 1512 54 N 1675 09 W 484 60 W 580 65 W 702 40 W 856 11W 1039 09 W 1216 27 W 1386 17 W 1550 24 W 1715 56 N 74 34 W 67 N 74 31W 23 N 74 48 W 56 N 75 16 W 53 N 75 53 W 29 N 76 23 W 83 N 76 49 W 62 N 77 13 W 73 N 77 32 W 3920 06 3047 O0 2900 O0 58 45 4113 4306 4499 4693 4888 5083 5280 5479 5680 17 3147 14 3247 41 3347 39 3447 19 3547 63 3647 53 3747 79 3847 95 3947 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 58 47 O0 58 51 O0 58 49 O0 59 5 O0 59 6 O0 59 21 O0 59 44 O0 60 5 O0 60 19 N 80 27 W 1879 43 N 80 13 W 2044 N 80 6 W 2209 N 80 0 W 2375 N 79 43 W 2541 N 79 28 W 2708 N 79 12 W 2876 N 81 27 W 3045 N 82 2 W 3218 N 82 12 W 3392 61 64 O3 25 43 33 94 17 54 0.28 0.16 0.46 0.21 0.28 O. 02 0.21 1.46 O. 52 0.27 397 82 N 1837 90 W 1880 46 N 77 47 W 425 453 482 511 541 572 603 628 651 57 N 2000 71N 2163 30 N 2326 66 N 2489 95 N 2554 98 N 2819 62 N 2986 O4 N 3156 80 N 3329 75 W 2045 37 W 2210 27 W 2375 88 W 2541 29 W 2709 31W 2876 12 W 3046 74 W 3218 65 W 3392 51 N 78 0 W 44 N 78 9 W 74 N 78 17 W 91 N 78 23 W 05 N 78 28 W 94 N 78 31W 52 N 78 34 W 61 N 78 45 W 84 N 78 55 W COMPUTATION DATE: 18-NOV-92 PAGE 6 ARCO ALASKA INC. 2M-O1 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 3-NOV-92 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5884 10 4047 O0 3900 O0 60 39 6088 6293 6497 670I 6905 7107 7311 7512 7704 61 4147 55 4247 75 4347 30 4447 17 4547 80 4647 O0 4747 i1 4847 34 4947 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 60 41 O0 60 45 O0 60 41 O0 60 34 O0 60 22 O0 60 24 O0 60 41 O0 59 23 O0 57 29 N 81 56 W 3569 23 N 81 51W 3747 N 81 56 W 3926 N 81 47 W 4104 N 81 22 W 4281 N 82 15 W 4458 N 82 4 W 4634 N 82 18 W 4811 N 83 28 W 4985 n 85 37 W 5149 50 26 17 36 86 95 68 87 50 0 28 0 61 0 49 0 43 0 36 0 53 0 89 0 38 0 84 1 90 676 44 N 3504 76 W 3569 44 N 79 5 W 701 726 752 778 802 826 851 872 888 67 N 3681 97 N 3858 05 N 4034 08 N 4210 66 N 4386 82 N 4560 O0 N 4735 43 N 4908 92 N 5072 36 W 3747 45 W 3926 71W 4104 08 W 4281 03 W 4458 61W 4634 83 W 4811 99 W 4985 31W 5149 63 N 79 13 W 34 N 79 20 W 20 N 79 26 W 37 N 79 32 W 87 N 79 38 W 95 N 79 43 W 69 N 79 49 W 91 N 79 55 W 61 N 80 4 W 7888 32 5047 O0 4900 O0 56 42 8071 8253 8431 8595 8749 8894 9032 9168 9304 11 5147 90 5247 78 5347 07 5447 14 5547 42 5647 22 5747 61 5847 21 5947 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 56 57 O0 56 12 O0 55 8 O0 49 52 O0 48 22 O0 44 23 O0 43 13 O0 42 28 O0 42 43 N 87 10 W 5302 82 N 87 4 W 5454 N 86 39 W 5606 N 86 17 W 5752 N 84 35 W 5880 N 85 4 W 5997 N 85 40 W 6102 N 85 27 W 6196 N 86 2 W 6288 N 84 47 W 6379 49 24 37 80 52 29 66 87 95 0 43 0 48 2 77 3 92 0 92 0 95 4 52 0 69 0 38 1 57 898 22 N 5226 45 W 5303 07 N 80 15 W 905 913 922 933 944 952 960 967 973 46 N 5379 29 W 5454 39 N 5532 09 W 5606 86 N 5678 89 W 5753 92 N 5807 42 W 5882 49 N 5924 13 W 5998 44 N 6029 18 W 6103 43 N 6123 64 W 6198 21 N 6216 13 W 6290 98 N 6307 47 W 6382 97 N 80 27 W 99 N 80 37 W 39 N 80 46 W 04 N 80 52 W 95 N 80 56 W 94 N 81 1W 50 N 81 5 W 93 N 81 9 W 23 N 81 13 W 9439.22 6047.00 5900.00 41 10 9570.01 6147.00 6000.00 38 35 9695.44 6247.00 6100.00 36 24 9800.00 6331.16 6184.16 36 24 N 80 34 W 6470.48 N 79 21W 6554.75 N 75 26 W 6630.31 N 75 26 W 6692.19 I . 82 3.28 0.00 0.00 985.34 N 6397 43 W 6472.86 N 81 15 W 999.89 N 6480 43 W 6557.12 N 81 14 W 1016.96 N 6554 13 W 6632.56 N 81 11 W 1032.56 N 6614 18 W 6694.30 N 81 8 W COMPUTATION DATE: 18-NOV-92 PAGE 7 ARCO ALASKA INC. 2M-O1 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK A LAST READING GCT PBTD 7'l CASING TD DATE OF SURVEY: 3-NOV-g2 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 114' FSL & 19' FWL, SEC27 TllN R8E UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3346.00 9436.00 9472.00 9472.00 9580.00 9652.29 9697.00 9785.00 9800.00 2749 20 6044 58 6071 74 6071 74 6154 81 6212 28 6248 26 6319 09 6331 16 2602 20 5897 58 5924 74 5924 74 6007 81 6065 28 6101 26 6172 09 6184 16 316 90 N 984 99 N 988 94 N 988 94 N 1001 04 N 1010 51N 1017 19 N 1030 33 N 1032 56 N 1353 84 W 6395 33 W 6418 62 W 6418 62 W 6486 56 W 6529 37 W 6555 03 W 6605 57 W 6614 18 W COMPUTATION DATE' 18-NOV-92 PAGE 8 ARCO ALASKa INC. 2M-01 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a LAST READING GCT PBTD 7" CASING DATE OF SURVEY: 3-NOV-92 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION : 114' FSL ~ 19' FWL, SEC27 TllN R8E UM MEASURED DEPTH BELOW KB TVD FROM' KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3346 O0 9436 O0 9472 O0 9472 O0 9580 O0 9652 29 9697 O0 9785 O0 9800 O0 2749.20 6044.58 6071.74 6071.74 6154.81 6212.28 6248.26 6319.09 6331.16 2602 20 5897 58 5924 74 5924 74 6007 81 6065 28 6101 26 6172 09 6184 16 316 90 N 984 99 N 988 94 N 988 94 N 1001 O4 N 1010 51N 1017 19 N 1030 33 N 1032 56 N 1353 84 W 6395 33 W 6418 62 W 6418 62 W 6486 56 W 6529 37 W 6555 03 W 6605 57 W 6614 18 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 9800.00 6331.16 6184.16 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6694.30 N 81 8 W DIRECTIONAL SURVEY COM~NY ARCO ALASKA INC. ;;r=u:~ KUPARUK RIVER WElL 2M-01 couN'mY USA .UN ONE t~'r; U:X~ED 03 - NOV - 92 D~PTP! UNIT FEET FIEFF-'"~'NC. 92661 ~ELL' 214-01 (114' .FSL, 19' FlaIL, SEC o T11N, R8E,IJH) HORIZONTAL PRO~ECTIO~ i -:'"}-":-'~"-"~ ........ ~""'~ ..... ~'"~ ..... ~"."":' ..... i'";---'}--."'-~ .... i'":":'-~ .... ~-o:--:--:---.-~--}--:.-2--~.-~-'~--i'-}-'1--¥.:--.¥-; .... ~-.~ ..... ~ ..... i.-~.':'--r'- -i"~--: ..... !.-:--? : ...... 2..!. :' -~--i-~~} ...... i'--!-~'-~ ..... i---..':--?- ...... i-.-Fi--i ..... i-.!---i ........ i...i...i. ..... i-..:.-.i-..!.-.l..i..i ................I i .... !.-;.-.~-i..i .... ~-.i..Li .... ~ ......... : .... . .......... ::--;--i..~ ....... ~.- ........ ?-??!- ..... !---!--!---! ....... !--!--'? .... !--!--!--'! ..... !--!--:--~! .... ! .............. !-.--.! ..... ~---!--!.-.! .... !-.i--~-.! ..... ~-~i.-! ...... ~ ...... ~ .......... ~"i :"~"~":":" "' ..... :": .... ~ ..... i"i ...... L.; :--L...~.. ~-.:.-.': .... :-~:.-.: ......... ~.. :.. :-. : : : ' : : : : : : : : ~ : : ~ : : : : · : : : ~ : : : · · ' ' : · -F"~.-£_i_~._L..L.L~~ ..... i_.L..i...i ..... :~ ~ '~ 'T' i'"i'"? i'"! ..... !"T"F-! .... !'"F"!'"F'i'"F'!-'!'"f ..... !" !'"f'"! ..... :"~'"F'~ ..... i" i" i"! ...... ~" !" i"! ":" ~'' :"! .... i" i" ~": ..... !" F i": .... i" !" ~'' !" --Fi--i-i- .....[ i--i---!--! I' i--i--i--:.--}--!: '"!"r-~" '~-~ r- -~--:-~ :--i--!--! ....... ~--:--! .... !--i ...... ~---: ....... t ........................... ~ .............................. ' ~---~--~---..--~..i--i--~--~,--!--~---;---!--!-.!--~--~--~ .... :-----~--i--t--~--?~ .... ~-i--:~--i..!- ~--~--~---,--~----~..!--t--!--~..~---i-~/--,.--i--~---~ ..... ~.-~-~i.,---.~--~--~..'- .... ~----.!--! .... '.. ~--:. ! ~ .... :-.-:4 ...... ~-.~-.; ..... :--~..:--: ...... ~.~~:>~.-:-~-,-,.:...:.-; ........... ,'-~'-I";"-; ...... ~:": ........ r';", ................. ~": .... ~' ..... : ................ -'~ ..... ~ .......... :'-: ........ :-"t ..... : ..... ~-'~ .......... ~ ....... ~--~--' :--- - - --:~o-~- .... :-.-!--! .......................................... :--~---!---i ...... ~ .... t ..... i .... !--~ ..... ~ ..... :.-~.-! ..... ~--i--i- .-~--"---~-~--~--.~. i--~O:~ -.~ --:.--i. ...... i ..... i.-!--~ ..... !--!--i.-, ................... :-.~..i- .... ~ ........ -..~...:.-..i..!-..,-..i.-i--!-...! .... ~...~-.!..-.i ..... ~-.!.~.-:--.I-Fi.-i--i ..... i---i--.i- ....... i ..... i---! .... i--.i--::---i ..... i-.!--.i.--i .... i .... i..-~.-i-.::..i...i ..... i ..... i--i .... i--!-.i..-:~ .... i-.-~:-.!.-.~- .... ~ ..... :.. I ........ :~i::~!~i~:i~::~:~i:'!~i~i~:'~::'i:~i:~'!~i~t~i~i~'i~i~l~.~i~i~i:~i~i~'!~'i~ :~'i~'!~'~"~ ....t I~"!"i"~ .... i----!--!-'! ..... '~-'!---'!--! .... !--i---i'-!- .... !-'-!'-!-'! ...... ! ...... ~ ..... !-'~'-!"i' ..... '"~'-. ~"~-" ..i.o.i_.i_i......!...i...i.. ~ .... L_.'....i.. i .... i.. i.. L..! .... :,...i.. i.. ~ .... i...i...L..i ...... :... ~.. !.. ~ ..... i.. L..i...!....-!...!...i-. i ..... i--!--i--i .... i--i- i.-i .... !-. !,-io- i ..... ~.- i-. i-. i- i .. i,,- i,, i,. i .... i-i.-i.,~.. :..-z ...... J.. ~ ; ~ ~ ; ; ~ i ! ! ! :. :. ! i :. ! i : : ! ! ! t ! ! : , i ! i ! : : ' ' ! ! ! ! i :, : ! ' : ?".."-"~ ...... ~"? ................. i'"'?'~ ..... !"~"?'-'! .... i" i" i"?" ,'"i'"?i'"Fi "i ..... i"?':i:':~::i~:: ::: '~ ' ~: '~ i ' '~ ' ':i! : ::::::::::::::::::::::::: ::::i::. :: :::::::::::::::: ::::::::::::::::: :: ::::::::::::::: ::::::: ::: :::::::: :::::::::::::::::: ::::::::::::::::::::: ::.i::!::!::!:-:-i--i---!--.!--!.-!---i-.-i---i .... i--!---hi--,.-!--!--!---i--I--i.-!---!--! .... i.-~..-!.-~- .... !'-i"!"! ..... !.-~:..~. i I':' -1OOOO -~DO0 ~ -44:~0 -20g-3 O ~ 4000 6~0 ~T WELL' 2N-01 (114'- FSL,'' 19' FWL, SEL ., T11N, R8E,UM) VERTICAL PROJECTION -4000 -~0 0 0 2000 4000 ~0 8000 AOGCC GEOLOGICAL MATERIALS INVENTORY LIST COMPLETION DATE ~ ,'Z- j~. /et ! O~Z.. CO, CONTACT ('~'T'~ PX~ check off or list data as' it is' receiv~d.*l!st received date for 407'. if not require,,d list as NR 407 I * ~ J Z~Jc~ drilling histo~ ~ survey} I ! well tests ~ ~ core descriptio~ ~L Cored intc~al~ core analysis ~ d~,ditch intcwals digital data ii LOG TYPE RUN INTERVALS SCALE ., NO. [to the ncarcst foot} [inchl100'] o) , , , lo,I 12) 13! 14} ._ 15) _ 16} 17') i i i i i i i ii i i i i i ARCO Alaska, Inc. Date: December 4, 1992 Transmittal #: 8614 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and 'return one signed copy of this transmittal. 2M_17~5¢~'¢' ,-.¢. LIS Tape and Listing ~ 1 1 - 1 9 - 9 2 9 2 4 0 9 2 M 0 1 ~ .5'?,; LIS Tape and Listing or/ 1 1 - 2 5- 9 2 9 2 6 4 0 2 M 0 8,/¢ ~,~6 LIS Tape and Listing o~ 1 1 - 3- 9 2 9 2 6 6 7 Receipt Acknowledged: ~-~ Date' RE-CE'VED DEC 0 7 DISTRIBUTION: Alaska 0il & Gas Cons. Commission Anchorage Lynn Goettinger State of Alaska ..iol ARCO Alaska, Inc. Date: December 4, 1992 Transmittal #: 8609 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-01 ,/ 2M-08 / Receipt Sub-Surface Directional 1 1 -03- 92 Survey Sub-Surface Directional 1 1,1 6-92 Survey Acknowledged :- ~- ~- DISTRIBUTION: D&M State of Alaska (2 copies) 92661 92684 RECEIVED D a t e :D-EC- -0-7--19-92 Alaska Oil & Bas Cons. Commission Anchorage ARCO Alaska, Inc. Date: November 13, 1992 Transmittal #: 8602 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 RECEIVED NOV 1 6 ~99~. _Alaska Oil & Gas GoDs. Commissio_rl Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. I 2M-01 Cement Evaluating Log ,..-"/ 1 1 -03-92 8700-9688 2M 01 Cement Bond Log ./~ 11-03-92 8700-9670 State of Alaska(+sepia) Receipt Drilling Acknowledge' NSK ARCO Alaska, Inc. Date: November 6, 1992 Transmittal #: 8595 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-01 ~ 1 0/25-29/92 3347-9800 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) NOV Oil & Gas CoDs. C'°~ssi°D MEMORANDUM ALASKA OIL AND GAS CONSERVATION COMMISSION STATE OF ALASKA to: Leigh A Griffin ~,' date: Commissioner file: thru: Blair E Wondzell ~,17.,~ subject: Sr Petr Engineer from: '~ou Grimaldi Petr Inspector October 29, 1992 LOU10211.DOC Diverter Inspection Parker Rig 245 (6597670) ARCO Well #2M-1 Kuparuk River Field #92-103 Wednesday, October 21, 1992: John Spaulding and I traveled to ARCO's facility in the Kuparuk River Field to witness the diverter function test on Parker Rig #245 which was preparing to start drilling well #2M-1. This rig has an impressive diverter system which consists of a Schaffer 5000 psi annulur preventer and two Demco ball type diverter valves. All components are quick acting with a full cycle of 45 seconds or less. Down wind or alternate vent line selection can be preset or changed form the drillers BOP control panel. It is Parker's policy to leave the vent lines loose on the outside of the divert valves during the test so operation can be visually verified. Also, after the test is concluded, the stack is filled with water to check for leaks past the valves, once satisfied as to their integrity, the vent lines are installed and bolted up. In summary, I witnessed a good diverter function test on Parker Rig 245 in the Kuparuk River Unit Attachment ALAS KA OIL CON S E RVAT I ON ~-'OMM I S S I ON THRU: Blair E Wondzell P.I. Supervisor FROM: Lou Grimaldi Petr Inspector DATE · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rig/BOPE Inspection Report OPERATION: Drlg~ Compl~ Wkvr UIC Operator /~)CO Permit #~- Location: Sec ~_~L~7 T //Y~/ R ~= M Location (gen'l)_~/_~P~AJ~ Well sign~ IN COMPLIANCE; yes no 9(9 A. DIVERTER ( ) line sz & length ( ) line corm & anchored ( ) bifurcated & dwn wind ( ) 90° targeted turns ( ) vlvs: auto & simultaneous ( ) annular pack-off ( ) condition B. BOP STACK ( ) wellhead flg wkg press ( ) stack wkg press ( ) annular preventer ( ) pipe rams ( ) blind rams ( ) stack anchored ( ) chke/kill lin~ sz ( ) 90° turns targeted (chke & kill ln) ( ) HCR vlvs (¢hke & kill) ( ) manual vlvs (¢hke & kill) ( ) connections (flgd, whd, clmpd) ( ) drl spool ( ) flow nipple ( ) fl ow monitor ' ( )' control lines fire protected C. CLOSING UNITS ( ) wkg press ( ) fluid level ( ) oprtg press ( ) press gauges .( ) sufficient vlvs ( ) regulator bypass ( ) 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel ( ) remote control panel ~.U~J () 6.(x} s.() ~o.() ~.C) 2o.() 22. (,) ( ) 24. { )* () 2s.{) 26. ( ) ( ) £7. ( ) ( ) 28.() () 29.() () 3o.() () 3'~. ( ) () 32. ( )- () DATE: . /~.0 ,-- Representative Well name c~ -/~/ Representative IN COMPLIANCE; yes n_~o n/a 34. ( ) 35.() 36.() 37. ( ) 38.() 39. ( ) ~0.() 41.() 42. ( ) 43.() 44.() 4s.() 46. ( ) 47. ( ) 48.() 49. ( ) 5o.() $'~. ( ) 52.() 53.() 54. ( ) 55.() 56.() 57. () 58.() ( ) ( ) firewall ( ) ( ) nitrogen power source (back-up) ( ) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM ( ) ( ) pit level floats installed ( ) ( ) flow rate sensors ( ) ( ) mud gas separator ( ) ( ) degasser ( ) ( ) separator bypass ( ) ( ) gas sensor ( ) ( ) chke In conn ( ) ( ) trip tank E. RIG FLOOR ( ) ( ) kelly cocks (upper,lower, IBOP) ( ) ( ) floor vlvs (dart vlv, ball vlv) ( ) ( ) kelly & floor vlv wrenches ( ) ( ) driller's console (flow monitor flow rate indicator, pit leve~ indicators, gauges) ( ) ( ) kill sheet up-to-date ( ) ( ) gas ~etection monitors (H S & methane) ( ) ( ) hydr chke panel ( ) ( ) chke manifold F. MISC EQUIPMENT ( ) ( ) flare/vent line ( ) ( ) 90° turns targeted (dwn strm choke Ins) ( ) ( ) reserve pit tankage ( ) ( ) personnel protective equip avai~ ( ) ( ) all drl site suprvs trained for procedures ( ) ( ) H2S probes ( ) ( ) rig housekeeping REMARKS: RECORDS: Date of last BOP inspection: Resulting non-compliance: Date of last BOP test: Non-compliances not corrected & ~y: Date corrections will be completed: BOP test & results properly entered on daily record? Kill sheet current? ,. ..... ALASKA OIL AND GAS CONSERVATION COMMISSION / I / / / ! WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 6, 1992 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100.360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-01 ARCO Alaska, Inc. Permit No: 92-103 Sur. Loc. ll4'FSL, 19'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc. 1356'FSL, 1527'FEL, Sec. 29, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Origi~ol $~gned ~? David W. doi_~neton David W. Johnston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AI.~,..,,;A OIL AND GAS CONSERVATION COMMIS,5...~ N PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Reddll [--1 lb Type of Well Exploratory r'l Slratlgraphic Test r~ Development Oil X Re-Entry [] Deepen r~ Service [~] DeveiopmentGas [~] Sinc~leZone X MuitipleZone [] 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 147', Pad 106' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora(:je, AK 99510-0360 ADL 25585, ALK 2671 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 19' FWL, Sec. 27, T11N, RSE Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1314' FSL, 1296' FEL, Sec. 29, T11N, RSE 2M-01 #UG630610 At total depth 9. Approximate spud date Amount 1356' FSL, 1527' FEL, Sec. 29, T11N, RSE 10/12/1992 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'T'VD) property line 2M-02 9942' MD 1356' @ TD feet 10.8' @ 540' MD 2560 6277' TVD feet 16. To be completed for deviated wells 17. Antlcipaled pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 800 feet Maximum hole angle 60.37° Maxirnumsurface I 626 osio At total doeth rTVDI 3113 18. Casing program Setting Depth size Specifications Tcp Bottom Quantity/ of cement Hole Casing Weight Grade Coupling Len~h MD TVD MD TVD Ilnclude stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" ~ L-80 BTC 3350' 41' 41' 3391' 2746' 260 Sx Permafrost E & F~ ~.),~,~ i~;/,~,;f../~ /--,/7. o HF-ERW 600 Sx Class G 8.5" 7'" 26.0# J-55 BTCMOC 4420' 41' 41' 4461' 3275' HF-ERW 8.5" 7" 26.0# J-55 BTC 5481' 4461' 3275' 9942' 6277' 160 Sx Class G HF-ERW Top 500' above Kul:)aruk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) Irue vertical feet Casing Structural Length Size Cemented jilt ~ .e.~ u~ ~1 ~j~.t~ [[.~ t-~True Vertical depth Conductor Surface Intermediate S E~ P ~ ~ Production '- ~'~ ~' ~--' LinerAlaska 0JJ & GaS Cons. ComI-RiS$iOl-~ Pedoration depth: measured ;Anch0raoe true vertical 20. Attachments Filing fee X Property plat [] BOPSke~c~ X Dlverter Sketch X Ddlllng program X Ddlling fluid program X Time vs depth plot r-1 Retraction analysis E] Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge S'.K~ed ~~~~ Title Area Drillincj Encjineer Date / Commission Use Onl~ Permit Number APl number I Approval dat~,/ I see cover letter for ?~ -//(~,.~ 5 O- ,//(:~ ..~ -.-- .~. (~ ,//p 5 ~) '- ~¢, ~ ~-~ other rec~ulrements Conditions ct approval Samples required D Yes .,~ No Mud logrequlred ~ Yes ..~ No Hydroo~n sul/ide measures r'~ Yes ~ No Directional survey re~uired ~ Yes [--~ No Required wortdng pressure for BOPE ~ 2M [] 3M ~ 5M D 10M ~ 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARC 0 ALASKA, Inc. Structure : Pad 2M Well : 1 Field : Kuparuk River Unit Location : North Slope, Alaska CnEATE0 aY : JO.ES For: B M. ATHEWS :DATE PLOTTED : 24~-SEP-92 PLOT REFERENCE !S I VERSION ~2. :COORDI~TES ~E IN FEET REFERENCE SLOT ~1. ~TRUE ~R~CAL OEPTHS ARE REFERENCE WEL~E~. ~LECO g ~ug~ o O o 350 .. 700 I,I --J Q) 1050 140Q 1750- 2100 i I I V 7600 7200 f I t I - 2800- - 3150_ 3500 - 3850- 4200 4550 . 4900_ ~ 5250- 5600- 5950- . 6300. 6800 6400 6000 5600 5200 *800 4-~O0 I I I I I I I I I I i I I TARGET LOCATION: I 1 314' FSL, 1 296' FEL SEC, 29, T11N, RBE <-- West 4000 3600 3200 2800 2400 2000 1600 1200 RKB ELEVATION: 14'6' I TO LOCATION: I 1356' FSL, 1527' FEL SEC. 29, Ti 1N, R8E SCALE 1 : 200.00 800 400 o 4-00 N 79.69 DEG W 6?03' (TO TARGET) KOP TVD=800 TMD=800 DEP=0 6.00 BUILD 3 DEG / 100' 12.00 lc,.00B/,.~ PERMAFROST TVD=1396 TMD=14-06 DEP=95 T/ UGNU SNDS TVD=1426 TMD=14-38 DEP=106 24-.00 30.00 36.00 T/ W SAK SNDS TVD=1996 TMD=2092 DEP=4-21 4-2.00 4-8.00 54-.00 60.00 EOC TVD=2460 TMD=2012 DEP=966 B/ W SAK SNDS -FVD=254-6 TMD=2986 DEP=lll7 9 5/8"CSG PT TVD=2746 TMD=3391 DEP=l¢68 K-lO TVD=2806 TMD---3512 OEP=IS?4. SURFACE LOCATION: 114-' FSL, 19' FWL SEC. 27, Tl lN, RBE TARGET ANGLE 40 DEG A/B MODIFIED CSG PT TVD=3275 TMD=44-61 DEP=2399 K-5 TVD=4296 TMD=6526 DEP=4194- 1600 ~ 20o _800 - _4oo o 400 MAXIMUM ANGLE RECEIVED BEGIN ANGLE DROP TVD=5133 TMD=B219 DEP=5665 DROP 1.5 DEG / 100' TARGET- T/ KUP SNDS - E0D TVD=5998 TMD=9577 DEP=6703 T/ ZONE A TVD=601¢ TMD=9598 DEP=6717 B/ KUP SNDS TV'D=612¢ TMD=9742 DEP=6809 TD/ LOGGING PT TVD=6277 TMD=9942 DEP=6938 CEP ~ 9 1392 Alaska 0il & Gas Cons. CommiSsiOn 5~.5o Anchorago 55.50 52.50 4.9.50 46.50 43.50 40.50 6650 ] ...... 1015011 I 171501L I ~ ..... 35100 I i ..... LI , I ti , , L,6615o 0 350 700 1400 21 0 2 50 28O0 3150 3 50 4-200 4550 49 O 5250 56 O 5950 63 0 SCALE 1 : 175.00 Verticol Section on 280.31 azimuth with reference 0.00 N, 0.00 E from slot #1 70100 4-00 :350 I I I ARCO ALASKA, Inc. Structure : Pad 2M Well : 1 PLOT INCLUDES PROPOSED WELLS: 8/29/31X Field : Kuparuk River Unit Location : North Slope, Alaska <-- West ~c^,~,. ~o.oo 300 250 200 1 50 100 50 0 50 100 6O0 1800 1000 ..'mT -.-= c,:~ ~' ~400 8OO ~0 600 1200 000 ~200 ~ko° 1200 000 800 1000 150 _100 -' _ 50 _ 0 _ 50 - I _100 - V _150 o . , , o . , , . 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M-01 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3391')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9942') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (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 to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED ,:~,Iaska Oil & "' , Gas Cons. Commission Ancl~orage DRILLING FLUID PROGRAM Well 2M-01 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~l 9.0-9.6 15-25 15-35 50-100' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling FIt~id 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 Notes: Weight up to TD 10.3 10-22 8-20 35-50 2-4 4-8 4-6 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1626 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-01 is 2M-02. As designed, the minimum distance between the two wells would be 10.8' @ 540' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 80-100 sec/qt to drill gravel beds. Aiaska. 0ii & Gas Cons. C0rr~rp. issio'n Anch0ra98 20" DIVERTER SCHEMATIC 6 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 5 4 5 5 MAINTENANCE & OPEFLRTIC)N 3 1 . UPON INIT1AL I~ISTALLATI(~, CLOSE PRE~~ AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNtX.a,R PREVENTER I~ THE EVENT THAT AN INFLUX OF WI:al ~ FLUE)S OR GAS ~S DETECIT=D. OPEN APPROPR~ VALVE TO ACHIEVE ~INO DIVERSIO~ ARCO~ I~C., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE ~ 20AAC25.035~) 1. 16' CONOtX3TC~ 2. SUP~4 W~LD STARTING HEAD 3. FMC OlVERTER ASSEbIBLY WITH TWO 2-1/16'- 2(XX:) PSI BALL VALVES 4. 20'.2,000PSIDRILLJNGSP(:X:)LWlTH TWO10' OtJTLETS. $. 10' HCR GATE VALVES win410- DIVERTER LINES, A SlqGtJ~ VALVE OPENS AUTOMA~Y UPON CLOSURE OF ANMA,N:I PREVENTEFL VALVES CAN BE REJVK~Y CONTROLLED TO ACHIEVE EX:)WNW1ND ~,~,laska OiJ & Gas Cons. Col-ri~-~issiO~ Anchorage 6 13 5/8" 5000 3. OGSERVE TIME. THEN ~ ALL UNITS S, IMULT~YAM) REC, ORD THE TIME ANO PRES:SURE REMAINING AFTER N.L UNIT'S ARE CLOSED WITH CHARGING PUMP OFF. 4. I::~CC~O ~ THE [ADC RE]:NDRT. THE ACCI~=TABLE ~ UMIT PRESSURE. 5 4 I3 2 1 BOP STACK TEST 1. fiLL BOP STACK AND MANI~ WITH ARCTIC DIESEL 2 CHECK THAT ALL ~WN SCREW~ ARE FULLY RETRACTED. PREDETERIViNE DEPTH THAT TEST PLUG W1U, SEAT ANO SEAT IN WELLHEAD. RUN IN LOCK-OOWN SCREWS IN HEAD. ~. CLOSE AJ~i~ PREVENTER ANO CHOKES AND BYPASS VALVES ON THE MANIr-~. ALL OTHERS CPEN. 4, TEST AU. ~ENT~ TO 250 P~ AND ~ FOR 10 MINUTES. INCREASE PRESSURE TO ~ PSI AND HOLD FOR 10 klNUTE~. BLEED TO ZERO P'3L ~ OPEN ANNULAR PREVENTOR AND MANUAL KILL ANO (:34OKE LINE VALVE[ & CLOSE TOP PIPE RAMS ANO HCR VALVES ON KlM, AND CHCX(E UNE[ 7. TEST TO 25~ PSI AND 31:XX) F:~t AS IN STEP 4. C,C~TINUE TE~ ALL VALVES, UNES, A/dO ~ WITH A 250 ~ LOW AND 3(X:30 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST & ANY C,,HOKE THAT I$ NOT A FULL CLOSING POSITIVE SEN. CHOKE. OPEN TOP PIPE RAMS ANO ~ BOTTOM PIPE ~. TEST BOTTCM [ RAN~TO~ ~ ~ ~ ~ OPEN PIPE RAMS. BACK~ RUNNING JTAND PULLCXJTOF HOLE tO CLOSE 9UNO ~ ANO TEST TO 3000 PS1 FOR 10 hlNUTES. BLEED TO ZERO PSI. OPEN BUN0 RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD 11. AND ~?- UNESARE FULL CX= ARCTIC {:XESEI. ANO ALL VALVES ARE SET IN TEST STANDPIPE VALVES TO 3eXPO PSL 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH K{:X)IvlEY PUke. RECORD TEST INFORMA~ ON Bt.~T PREVENT-eR TEST FORk[ AND SEND TO DRJLUNG SUPERVISOi:[ PERFORM COMP~ BOPE TEST ONCE A WEE)< AND FUNCT1CNALLY PiPE RAM~ ON TOP, BLIND ~ ON BTM 7. 13..S~- 5000 PSi AN~ /-,,rlCriO~ Casing Design / Cement Calculations 28-Sep-92 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg A MD.' Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice (1, 2, 3, or 4): Production Csg A Choice (1 or 2): Production Csg B Choice (1 or 2): Production Casing Frac. Pressure 2M-01 3,391 ft 2,746 ft 4,461 ft 3,275 ft 9,942 ft 6,277 ft 2,092 ft 9,577 ft 5,998 ft 10.3 ppg 3,500 psi ** See Page 4 For Casing Choices Maximum anticipated surface pressure TVD surface shoe = 2,746 ft {(13.5'0.052)-0.11}*TVDshoe =l 1,626 psiJ Estimated BH pressure at top of target zone Anticipated Mud Weight Top of Target Zone, TVD 100 psi Overbalance 10.3 ppg 5,998 ft 3,213 psi 3113 psiJ Surface lead: Top West Sak, TMD = 2,092 ft Design lead bottom 500 ft above the Top of West Sak = 1,592 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 499 cf Excess factor = 15% Cement volume required = 573 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 260 sxJ Surface tail: TMD shoe = 3,391 ft (surface TD - 500' above West Sak) * (Annulus area) = 563 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 598 cf Excess factor = 15% Cement volume required = 687 cf Yield for Class G cmt = 1.15 ~ E?~ '"~,~' L~ '~-' Cement volume required =1 600 sxJ Casing Design / Cement Calculations 28-Sep-92 Production tail: TM D = 9,942 ft Top of Target, TMD = 9,577 ft Want TOC 500' above top of target = 9,077 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 151 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 168 cf Excess factor = 15% Cement volume required = 193 cf Yield for Class G cmt = 1.23 Cement volume required =1 160 sxJ TENSION - Minimum Design FactQr$ are: T(_ob)=l.5 and T(j$)=I.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = 9.6ppg*.052*TVD Surf. Cas.*X-sect. Area Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = 9.6ppg*.052*TVD Surf. Cas.*X-sect. Area Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy =Mud Gradient*.052*TVD Pred.*X-sect. Area Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy =Mud Gradient*.052*TVD Pred.*X-sect. Area Casing Rated For-' Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = V ~ ~ Tension (Joint Strength)= . Design Factor =1 916000 lb 3,391 ft 40.00 Ib/ft 135640.0 lb 15700.9 lb 119939.1 lb 7.61 979000 lb 3,391 ft 40.00 Ib/ft 135640.0 lb 15700.9 lb 119939.1 lb 415000 lb 9,942 ft 26.00 Ib/ft 258492.0 lb 25379.8 lb 233112.2 lb 1.81 490000 lb 9,942 ft 26.00 Ib/ft 258492.0 lb 25379.8 lb 233112.2 lb 2.1J Casing Design / Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy =Mud Gradient*.052*TVD Prod.*X-sect. Area Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy =Mud Gradient*.052*TVD Prod.*X-sect. Area Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) Design Factor BURST' Minimum Design Factor = ..~ ~ ~, E IV ~' ~) Casing Rated For: Surface Casing: Burst = Maximum surface pressure Max Shut-in Pres = " ~""~ Design Factor =[ Aiask~ 0ii & Gas Cons, Corn Production Csg A: Anch0r~tge Casing Rated For: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Inside pressure Outside Pressure Net Pressure Design Factor Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For.' Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 28-Sep-92 4150O0 lb 5,481 ft 26.00 Ib/ft 142506.0 lb 25379.8 lb 117126.2 lb 49O0OO lb 5,481 ft 26.00 Ib/ft 142506.0 lb 25379.8 lb 117126.2 lb 4.2J 5750 psi 1625.6 psi 3.5J 4980 psi 5254 psi 1516 psi 3738 psi 1,3J 4980 psi 6862 psi 2905 psi 3957 psi 1.31 3090 psi 0.536 Ib/ft 1471 psi 2.1J 4320 psi 0.536 Ib/ft 1754 psi 2.5J 4320 psi 0.536 Ib/ft 3362 psi 1.3J Casing Design / Cement Calculations 28-Sep-92 OD ID Ib/ft I 9.625 8.681 47 2 9.625 8.835 40 3 9.625 8.921 36 4 10.750 9.950 45.5 Surface Casing Choices Grade Metal X-Section Jt Strength L-80 13.5724 sq. in. 1161000 lb L-80 11.4538 sq. in. 979000 lb J-55 10.2545 sq. in. 639000 lb J-55 13.0062 sq. in. 931000 lb Body Strength Collapse Burst 1086000 lb 4750 psi 6870 psi 916000 lb 3090 psi 5750 psi 564000 lb 2020 psi 3520 psi 715000 lb 2090 psi 3580 psi OD ID I b/ft I 7.000 6.276 26 2 7.000 6.276 26 Production Casing Choices Grade Metal X-Section Jt Strength L-80 7.5491 sq. in. 667000 lb J-55 7.5491 sq. in. 490000 lb Body Strength Collapse Burst 604000 lb 5410 psi 7240 psi 415000 lb 4320 psi 4980 psi Alaska, 0il & Gas Co,,~$. Con]tnis$io~] Anchorage ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS APPROVE DATE (3) Admin (4) Casg (5) BOPE [9 thru 13] 10. 9I olgv___ ii. IlO 8 13] i2. 13. [ 14 thru '22 ] 15. [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. j~/ . 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. L 6 Is well to be deviated & is wellbore plat included ................... 7 Is operator the only affected party .................................. 8 Can permit be approved before 15-day wait. Lease & Well NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nunber appropriate .......................................... Does well have a unique name & number ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old well bore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic g list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~OC)~) psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other /?~ ~//~/~ E29 thr~ 31]' (7) Contact (8) Addl geology' engineerinq: DWJ MTi~.~.~- RAD ~ fi- ) ~ LAG rev 08/18/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' 0 .-.{ '-rZ ~---~ 0 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. ALASKA COMPUTING CENTER *mmmmmmmm~m~m~mmmmmmmmmm~mmmm~ ,------- SCHLUmBERGeR ~mmmmmm~mmmmm~mmmmmmmmmmmmm~ ****************************** FIE~D NAME ~ KUPARUK R~VER BOROUGH ~ NORTH SLOPE STATE. J' ALASKA API NUMBER REFERENCE NO 5 92640 RECEIVED APR 02 1995 Alaska 011 & Gas Cons. Commission Anchorage chlumberger laska Comput ng Center 25-MAR-1993 09:56 ]RD STRING PRODUCTION STRING ~MARKS~ FIELD ENGINEER'S REMARKSI RGS READOUT PORT TO 8IT~ 68,9', GR TO BIT~ 76.2' RESISTIVITY TO B~TI 65 DRILLED INTERVAL: 3347~ -'9239' · . RGS READOUT PORT TO BITI 29,20'. GR TO BITI 36,5', RESISTIVITY TO BIT: 26,0' MAD PASS WASH DOWN INTERVAL 9172 ' - 9800' SLIDE ENTIRE WASH DOWN INTERVAL, SLIDING INDICATOR NOT PRESENT ON TABI ~AD PASS ~PPROXIHATEL~ 26 HOURS AFTER DRILLING, WASH DOWN DATA SA.PLED EVERY SECONDS.: DRILLING DATA S~PLED EVERY ~0 SECO DS., DATA~ N FROM DO~NHOLE MEMORY, SOFTWARE V2,3D/4.0C ****. FILE HEADER FILE NA~E I EDIT ,001 VERSION : 001A07 DAT~ : 93/03/25 MAX REC SiZ~ .c 1024 F!~E TYPE: : LO LAST FILE PAGE: F'IL~:HEADER FILE NUMBERI l EDITED ~ERGBD MWD _.DePth s~iited and:cl{PPed curves:! ali bit ru~s meroed, DEPTH INCREMENT 0'*5000 KRU~TOOL CODE STA. R'T DEPTH sTOP DEPTH ~WD 3347.0 9800,0 $ B S~L!N£ CURVE~ FOR SHIFTS: ' UNSHIFTBD BASELINE DEPTH' ~WD 9660 9656,0 9602,0 9597.5 IS ?a~e verificat~on bistin.q chlumberqer AlasKa Computin_q Center 2§-MAR-1993 09:56 PAGE) 9570 5 9512 5 9506 5 9488 0 9485 $ 9439.5 9376.0 9323 9305 9283.$ 9272'0 9249,5 9214.0 66.0 9161.0 9137.0 9i20.$ 9093 5 9083 0 90625 904? 0 9038 0 9018 5 8988 0 8556:0 8?2.4,0 100o0 M~RGED DATA SOURC~ ~RU TO~L COD~ RMM~RK$~ 9567.0 9507.5 9502.0 9483.5 9481.5 9436.5 9374.0 9346.0 9320.0 9302,0 9291,0 9280,0 9268,5 9244,5 9209,0 9161,0 9[59,0 9157,0 9i33,5 9217 0 090'0 ~080.5 9O 9 -0 901 8984,5 8852,0 8719.5 95.5 BIT RUN NO. MERGE TOP 1 3347,0 2 9239, 0 9239..0 9800.0 THE DEPTH SHIFTS ABOvE'REFLECT ~WD GR TO CASED HOLE G.R FROM CET/CBT RUN ON 03-N'OV-92 PER WOLCOTT,~ Abb OTHER CURVES WERE CARRIED WITH THE GE SH'IFT, , ., THE:CURVE NAMES FOR THE SA~P~I~O TICKS. ARE RTCK (RGS) & GTCK (GR).. THE SAMPLINO..TICK~ THAT APPEA~ IN THIS FILE ARE SAMPLED AT .5 FT.: HOWEVER, THE ACTUAL SAMPLE ~.ATE. IS A VARIABLE RATE.: ?HE SECOND~ FILE WILb CONTAIN ~HE TICKS A'T .I FT' SAMPLING WHICH WILL MORE ACCURATELY REPRESENT THE FIELD..DATA, .... ***** WASHDOWN DATA'ONLY.FROM 9239' TO ~AD PASS APPROXIMATELY 26 HOURS AFTER DRILLiNg,= IS ?ape Vert~ication List[nc chlumberqer AlasRa ¢omputtnq Center 25=MAR-J993 09:56 PAGE~ DATA FORMAT SPECIFICATION RECORD SET TYPE = 64ES TYPE REPR CODE VAbUE ! 66 0 2 66 0 3 73 36 4 66 5 66 6 73 ? 65 9 65 · 66 28 13 66 0 ~4 65 FT 15 66 68 16 66 0 66 0 ** SET TYPE - CHAN ** NAME' SERV UNIT SERVICE API AP1 APl APl FIbE NUMB NUmB SIZE REPR PROCESS ID ORDER $ LOG TYPE CSASS ~OD NUmB SA~P ELEM CODE (HEX) DEPT FT 6i8977 O0 000 O0 0 .i I I 4 68 0000000000 RTC~ MWD S 618977 O0 000 O0 0 i ! I 4 6.8 00000'00000 GTC~ MWD S 618977 O0 000 O0 0 I ! ! 4 68 0000000000 T~B MWD HR 619977 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OHMM 618977 O0 000 O0 0 i ! 1 4 68 0000000000 RP MWD OHMM 618977 O0 000 O0 0 ~ ~ I 4 68 0000000000 ROP MWD F/HR 618977 O0 000 O0 0 I ! ! 4 68 0000000000 GR MWD GAP! 618977 O0 000 O0 0 I 1 I 4 68 0000000000 SNR MWD D~ 6~8977 O0 000 O0 0 I ! 1 4 68 0000000000 - ROP'MWD !.24...~:37 SNR..MWD -999.250 RA,MWD ~.25~ RP,MWD 3,517 ROP*~WD 8N~.MWD -999.:250 TAB,, !~WD G: R ' M W D GR°N~D :'999,250 '"999.250 0,135 10:1,949 I8 Ta~e Verification L~[stinq chlumberqer AlasKa ComPuting Center DEPTo 9400.000 RTCK'MWD RR.MWD 1.728 RP.MWD SNR.MWD -999.250 D£PT. 9200.000 R?¢K.MWD RR.MWD 3.417 RP.MWD SNR.MWD -999,250 D~PT. 9000.000 RTCK,MWD RA.MWD ~.~ RP.MWD D~PT 8800.000 R?CK.MWD RA:MWD :164 RP.MWD 8NR.MWD 510'250 DEPT 8400.000 RTCK'MWD SNR.MWD 21 '300 DEPT., 8200.000 RTCK"MWD RA'MWD 2.585 RP'MWD 8NR.MWD 480.250 DEPT' 8000.000 R~CK.'~WD s....wo oo RA.HWD 3 35 RP.MWD 8NR.MWD 49850 DEPT..~, 7600.000 RTCK'MWD RA.MWD 3-562 RPeMWD SN~'MWD 498'700 DEPT 7400.000 RTCK~MWD Ra:MWD 3.298 RP,MWD SN~,MWD 469,400 DEPT,. 72OO'OOO RA,~WD 3,909 ~P'MWD R~.MWD 4,.. !2 RP.~WD SNR,MW'D, 25-MAR-J993 09:56 '999.250 GTCK..MWD 1.915 ROP.MWD '999.250 GTCK.MWD 3.486 ROP.MWD 250 GTCK.MWD '99~"188. ROP.MWD -999.250 GTCK.MWD 4 16 ROP.MWD ~.000 GTCK.MWD 4.929 ROP.MWD 1.000 ~TCK'MWD 2.675 ROP.MWD 232 ~OP'~WD I:ooo 129 3.320 ROP,MWD .250 GTCK~:MWD "99~'453 ROP.MWD -999.~50 GTCK~MW~' 4'43) ROP.NWD -999.250 457.984 1.000 294.168 1.000 334..i99 -999'250 461.438 163 294.552 '999'250 435'262 47~.:030 1,:000 600.024 5 .554 1~.000 579'631 .015 -999'~250 56~'265 TAB.MWD GR.MWD TAB.MWD GR.MWD TAB.MWD GR.MWD TAB'MWD GR.MWD TAB.MWD GR.MWD TAB.MWD GR.MWD TAB.MWD GR.MWD TAB~MWD GR,MWD TAB'~D GR.MWD TAB,MWD GR,MWD T.A,.B:,MWD GR,~WD TAB,M. WD GR.:MWD TAB'~WD GR'MWD PAGE~ 064 0.164 199.673 0.405 118,484 0,252 111,626 0,617 105.015 0:769 0 65 1:22,741 O,ii7 87,70~ 120.155 8.650 0,~53 137'491 Tape Verification Listing :hlumberger AlasKa Computing Center DEPT'. 6500.000 RTCK.MWD SNR,MWD 4! D~PT 6600.000 RTCK~MWD SNR..wo 3e .2oo DEPT: 6400.000 RTCK'~ND RA MWD 2,1gl RP.M. WD SNR~MWD 362.200 DEPT' 6200.000 R?CK~MWD ~NR.MWD 800 DEPT' 6000.000 RTCK.MWD 8NR.,WD 4! 950 DEPT'~ 5BO0'O00 RTCK'MWD RR.MWD 3,'464 RP*MWD SNR.MWD 410.850 DEPT' 5600 RTCK"MWD SNR'MWD 410,800 D~PTi 5200":000 RTC~':MWD 8NR.MWD 300 D~P?,: 5000"000 RTCK-MWD R ~. M W D ) -34 ? R P,. M W D 8NR'MWD 342'450 SNR.MWD 323.750 D£PT':: 4600.000 RA,MWD )~jBO0 R~.MWD 8NR'MWD DEPT 4400'~000 RTCKi, MW.D RA'MWD 3.556 RP,MWD 8NR:~WO 25-MAR-1993 09t56 [.000 GTCK.MWD 3,398 ROP,MWD -999,250 GTCK,MWD 2.021 ROP. MWD -99~,250 GTCK.MWD ~.252 ROP.MWD -999,250 GTCK.HWD 2,297 ROP.MWD 1,000 GTCK,MWD 3.287 ROP.MWD '99~':~50 GTCK.,WD 69 ROP,MWD 388 ROP'MWD 3.1. 1 ROP,~WD ,223 ROP.:MWD 3.328 ROP,M~D : -999-2~0 GTCK.~WD 3,5 6 ROP.M~D :845 ROP,MWD GTCK~MWD -999.250 540.012 ! 000 "999'250 497.290 'ooo 248.053 '999,~250 58~.842 -999~250 595.677 1~000 629.489 1:.000 554'320 8'647 · 61~: 50 '999*,250 55.5~'457 623-893 '9991'2,50 5:18.710 TAB'MWD GR.MWD TAB'MWD GR.MWD TAB"MWD GR,MWD TAB'MWD GR.MWD TAB'MWD GR.MWD TAB~MWD GR.MWD TAB'MWD GR.MWD :TAB'MWD GR'~WD TABoMWD GR,MWD TAB~MWD GR'MWD TAB,,MWD TAB,MWD GR.MWD TAB~MWD GR.:MWD PAGE; 04~ 0.292 115.390 0.311 124.799 3O? 429 0..t68 81'718 0'235 106'342 93.760 88,008 102'522 0'155 102~925 Tape Verification List~nq cl~lumberqerAlaslca Computing Center D£PT 4200.000 R?CK,~D R~:MWO 3.932 RP.MWD SN~eMWD 316.350 · D£PT. 4000,000 RTCK.MWD RR.MND 3,961 RP.MWD SNR,MWD 319,100 DEPT' ~800,000 RTCK'MWD RA.MWO 6.023 RPeMWD 8NR.MWD 322,400 DEPT. 3600.,000 RTCK'MWD SN...wO 32 95O DEPT' 3400,000 RTCK'MWD R~.MWD 5.558 RP.MWD SNR.MWD 352.450 D~P?. 3347,000 RTCK'MWD SNR.MWD 346 65 25-MAR-1993 09=56 -999.250 GTCK.MWD 3.929 ROP,MWD -999.250 G?CK'MWO 3.916 ROP,MWD 1.000 GTCK,MWD 6.090 ROP.MWD '999.250 GTCK.MWD 4.523 ROP,MWD '999,250 GTCK,MWD 5,504 ROP,MWD '999,250 GTCK,MWD 4.533: ROP,MWD -999.250 472.317 . -999.250 483.155 -999.250 539.110 1.000 561.28! -999 250 ! O0 TAB.MWD GR.MWD TAB.MWD GR.MWD TAB.MWD GR.MWD TAB..MWD GR.MWD TAB.MWD GR.MWD TAB.MWD GR.MWD PAGE= 0.111 94.925 0,192 111.065 . 0 223 0.236 107.367 89 FiLE NAME = EDIT ,001 SERVICE:: VERSION DATE: = 93t03/25 MAX REC SIZE : 1024 FILE TYPE **.** FIhE HEADER.. FILE NAME l: EDIT .002 DATE ~AX R~C;SI:ZE' ~ I024 FILETYPE bAST FiLE FILE HEADER FILE NU.BER 2. R~kW ~WD Curves and log header data ~or each blt run in separate tiles'.: IS Tape Ver~fication Listing 25-MAR-1993 09~$6 PAGE~ BIT RUN NUMBERI. DEPTH INCREMENT~ O,1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 3347,0 $ bOG-HEADER DATA DATE bOGGEDI 8OFTWARE SURFACE sOFT~ARE VERSIO~ DOWNHObE SOFTWARE VER$IONI DATA TYPE ¢~E~ORY OR REAL-TIME)~ ?D DRILLER TOP bOG INTERVAL aO?TO~ ~OG'INTEaV~ BIT ROTATIONAL. SPEED HOLE INCLINATION. (DEG) MINIMUM ANGbEI ~AXIMUM ANGLEI TOOL STRING (TOP TO BOTTOM) VENDOR TOO~ CODE TOOL TYPE CDR ESISTIVITY # ~DREHObE AND CASING DATA OPEN HOLE BIT SiZE DRILLERS CASING DEPTH FT)~ BDREHO~E CONDITIONS MU TYPE DENS (LB/G MUD VISCOSITY ~UD ~UD CHLORIDES MAXIMUM RECORDED MUD AT ~EASURED TENPERATURE .u~ A~ .AX C~RCU~A~ZN~ NEUTRON TOOL ~ATRIX DENS~TYI HOLE CORRECTION TOOL STANDOFF (IN ~WR FREQUENCY (HZI~ STOP DEPTH 9800,0 ~9-0CT-92 FAST 2,30 V4,0 MEMORY 9800,0 9800..0 334.7~0 ~8oo:o 8'500 334, 7.0 ~S~D 10,30 ~'~S.o ~.:57~ 2,372 :SANDSTONE :2.65 8,500 7'3,0 73,0 chlumberger Alaska ComPutin~ Center 25,'.~AR-1993 09:56 PAGE: # ~-EMARK$: FORMAT THIS FILE CONTAINS TICKS FOR RUNS $ DATA THE GR AND 2. RESISTIVITY SAMPLING DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 12 4 66 255 5 66 6 73 7 65 9 65 ii 66 85 12 68 13 66 0 1.4 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN N~E SERV UNIT SERVICE APl APl iPI APl FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS NOD NUMB SAMP EbEN CODE (HEX) DEP? FT 618977 00 000 O0 0 2 ~ I 4 68 0000000000 RTC~ 005 S 6189:77 O0 000 O0 0 2 t I 4 68 0000000000 GTCK 005 S 618977 O0 000 O0 0 2 I I 4 68 0000000000 *,* DATA ** D~PT' 3.272,900 RTCK,005 -999.250 GTCK.O05 1'000 DEBT 3399'900 RTCK , ,005 !:,000 GTCK'.O05 -999.:250 DEPT. 3400'I00 RTCK~005 1o000 GTCK,O05 -999,250 IS Ta~e Verification bisti~O chlumber~er ~las~a ¢o~utinC Center DEPT, DEPT. DEPT, DEPT. DEPT, DEPT, DEPT. DEPT' DEPT. DEPT. DEPT. DEPT. DEPT, DEPT. .. DEPT, DEPT' DEPT, DEPT, DEPT, DEPT* D~PT, DEPT. DEPT. DEPT, DEPT, DEPT, 3599.900 RTCK"O05 3600,I00 RTCK.O05 3799,900 RTCK.OO5 3800.100 RTCK.O05 3999.900 RTCK.O05 4000,100 RTCK.O05 4199,900 RTCK'O05 4200.101 RTCK,O05 4399.900 RTCK.O05 4400,i0! RTCK'O05 45991.900 RTCK.O05 4600.101 RTCK~O05 4799',900 RTCK'O05 48001.101 RTCK'O05 .T:C OO · 50001'101 RTCK.O05 5400,::101 RTCK~O05 · 5599.9o0 RTCK O05 $600.!101 RTCK,O05 5799,900 RTCK'O05 59991'900 RTCK.O05 25=MAR-1993 09:56 =999.250 GTCK.O05 -999.250 GTCK,O05 -999.250 GTCK.O05 -999,250 GTCK,O05 -999.250 GTCK,O05 -999.250 GTCK,O05 -999.250 GTCK,O05 -999.250 GTCK.O05 -999.250 GTCK,O05 -999.250 GTCK.O05 -999.250 GTCK,O05 -999'250 GTCK'O05 -999,250 GTCK,O05 -999,250 GTCK'005 -999.250 GTCK',O05 -999.250 GTCK'O05 -999'250 GTC:K.O05 '999,250 GTCK.O05 -999'250 GTCK.O05 -999,250 GTCK.O05 -999,250 GTCK,O05 -999,250 GTCK,005 ~.000 GTCK,O05: 1.000 ~GTCK-O05 -999,~50 GTCK,O05 -999,~50 GTCK'O05 =999.~50 -999.250 =999.250 -999.250 -999.250 -999.250 1'000 1.000 -999'250 -999'250 '999.250 -999'250 -999.250 -999'250 '999,~250 '999',,:250 '999:~250 '999.250 -999:,250 ~999"~50 -999.250 1'.000 -999.250 '999,250 '999.~50 -999.~50 PAGE: 10 IS ?a~e'ver~.icat~on List[nc chl~mber~er Alaska ¢omput~nQ Center D~PT, DEPT. D~PT, D~PT, DEPT. DEPT. D~PT. D~PT*~ DEPT. DEPT' DEPT' DEPT. DEPT* D~PT' DEPT,~ D£PT' DEP?' DEPT. DEPT.< DEPT*! DEPT* D~PT. DEPT' 6199.900 RTCK.O05 6200.101 RTCK.O05 6399.900 RTCK.O05 6400.101 RTCK.O05 6599.900 RTCK'O05 6600.101 RTCK.O05 6799'900 RTCK.O05 6800'~01 R?CK,O05 6999,900 RTCK.O05 7000,101 RTCK'O05 7199'900 RTCK~O05 7200"101 RTCK"O05 73'99,900 RTCK~O05 7400'I01 RTCK',O05 7599,900 RTCK~:O05 CK,,OOs 7799'900 RTCK,O05 7800'~01 RTCK~O051 7999,900 RTCK~,O05 8000,~01 RTCK~:O05 8199,900 RTCK-O05 8200"~100 RTCK'~005 8399'900 RTCK~O05 8400,~00 RTCK~O05 8599,900 RTCK~O05 8600'~00 RTCK',O05 09:56 -999.250 GTCK,O05 -999.250 GTCK.O05 -999.250 GTCK,O05 1,000 GTCK.O05 -999.250 GTCK,O05 -g99.250 GTCK.O05 1.O00 GTCK.O05 -999,250 GTCK.O05 -999.250 GTCK.O05 '999o250 GTCK.O05 -999.250 GTCK.O05 -999.250 GT'CK,O05 -999'250 GTCK,O05 -999.250 .GTCK,O05 -999.250 GTCK'O05 "9'99'250 GTCK,O05 -999'250 GTCK'O05 -999,250 :GTCK'005 -999,250 GTCK'O05 l,O00 GTCK'O05 -999,250 GTCK'O05 -999.250 GTCK'O05 -999.250 GTCK,O05 '999'250 -999,250 GTCK.-O05 -999,250 GTCK,O05 1,O00 l.O00 -999'250 -999.250 -999.250 -999'250 -999.250 -999.250 -999'250 -999.250 -999.~50 -999.250 -999',:250 -999'250 '9991,250 -999:'250 1'000 1',000 '999',250 '999.250 -999*250 '999'250 .999'250 '999.250 PAGE: Il I8 Ta~e verifica~ion List~n~ chlumberger Alaska ¢o~putlnO Cen~er D~PT.: 8799.900 RTCK.O05 D~PT, 8800.100 RTCK.O05 DEPT. 8999.900 RTCK.O05 DEPT. 9000.100 RTCK*O05 DEPT. 9199.900 RTCK'O05 DEPT. 9200,t00 RTCKoO05 D£PT. 9399.900 RTCK.O05 DEPT' 9400~I00 RTCK.O05 D~PT. 9599'900 RTCK.O05 DEPT.- 9600,100 RTCK'O05 DEPT' 9773.201 RTCK.O05 END OF DATA 25-~AR-1993 09C56 -999,250 GTCK'O05 -999,250 GTCK,O05 -999'250 GTCK,O05 '999.250 GTCK',O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 ~.000 GTCK.O05 1.000 GTCK,O05 1.000 GTCK.O05 -999.250 =999.250 1.O00 1.O00 -999.250 '999'250 1.000 1.000 1.000 1.000 PAGEt 12 **** F'IL~ TRAIbER FXL~. NAME I EDIT ,002 SERVICE : Fb:I~O7 VERSION : 001 DATE = 93/0,3/25 MAX REC:.SIZE .t 1024 FILE TYPE : LO hAST FILE _**** FILE'HEADER ***,* FILE MAMB { EDIT ,003. V~RSION . oo~Ao~ DAT~ : 93/03/2'5 MAX EEC S!ZE I 1024 FIST FILE ~ bALE TYPE , LO FIbE HEADER FILE NUMBER RAW MWD Curves and Iog BIT RUN NUMBER: DEPTH INCREMENT: 3 header Oata for each bit' run 0. 5000 in separate ~i[les. IS Taue Veritication L~stlng chlumberger Alaska Computing Center 25-MAR-1993 09156 13 # FIL~ SUMMIRY. VENDOR TOOL CODE START DEPTH CDR 3347,0 bOG HEADER DATE bOGGED: SOFTWARE SURFACE SOFTWARE VERSIONI, DOWNHObE SOFTWARE VERSIONI ~ATA TYPE (MEMORY OR REAL-TZME)~ TD DRILLER (FT)~ TD LOGGER(FT)= ' TOP ~OG ~NTERVAb (FT)= . 8OTTO~ LOG fNTERVAL (FT)= ~IT ROTATIONAt,.$PEED ~OLE..'~NC~INATION. (DEG) ~IN~U~ ANGbEI TOOL STR~NG (TOP TO BOTTOH) V£NDOR TO0~ COD~ TOOL TYPB CDR RESISTIVITY $ BOREHO~:E AND: CASING DATA STOP DEPTH mmmmmmmemm 9239,0 29-0CT-92 FAST 2,3D V4,0 MEMORY 'o.o 3347 8.500 33.4'7' 0 bSND 10,30 ~UD C'HbORIDE$ F~UID bOSS NBUTRON TOOL ~ATRIX{ ~ATR]X DENSITY{ HOLE CORRECT]ON TOOL STANDOFF ~WR FREQUENCY SANDSTONE 2,65 8,500 V ,o 73'.0 IS Tane Verification b[stinq chlumberqer AlasKaComputing Center 25-MAR-1993 09556 RG$ READOUT PORT TO BIT: 68,9'. GR TD BIT) 76 2' DRILLED INTERVALs 3347' ;~239' DRILLING DATA SAMPLED EV~- 20 ~ECONDS, DATA FROM DONNHOLE MEMORY, SOFTWARE V2,3D/4,0¢ SLIS FORMAT DATA PAGE: 14 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** m~mmmmm~mmmmmmmmmmmmmmmmmmm~mm TYPE REPR~CODE.~ VALUE mmm~mmmmmmmmmmmmmmmmmmmmm~'mmmm ! 66 0 4 66 5 66 ? 65 11 66 51 t2 69 ° 65 FI 5 66 68 6 66 1 0 66 ** SET TYPE - CH,AN mmmm~mmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmm~mmmmmmmmmmmmm~mm~mmmmmmmm~mm~"~m~mmm~m~m~mmmmm NAME SERV UNIT SERVICE AP1 APl AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYP~ CLASS MOD NUMB SAMP ELEM CODE (:HEX) D~? FT 6t$977 O0 000 O0 0 3 ! ! 4 69 0000000000 ATR bWi OHMM 61~977 O0 000 O0 0 3 I 1 4 69 0000000000 P:$R LWI OHMM 619977 O0 000 O0 0 3 1 I 4 68 0000000000 ROPE LW! F/HR 618977 O0 000 O0 0 3 1 I 4 68 0000000000 GR LWI GAP! 619977 O0 000 O0 0 3 1 1 4 68 0000000000 DATA IS ?aPe Verification 6lst[no chlumberoer Alaska Computin~ Center D~PT.~ 9238.500 ATR'LWl GR.LWX -999.250 D~PT, ~200,000 ATR,LW1 G~,LWX 999,250 DEPT'. 9000'000 ATR'LWI G~.LWl 132.107 DrPT 8600.000 ATR.LWl ~i 00~ D£P?, 84 '21 GP.LW1 . D£P?. B200.O00 A~R.LW1 G~.LW! 114.117 D~PT.~ 8 0 ATR*LWI DEPT' 7800,000 GR.LW{ 103~:150 DEmT' 7600,000 ATR'LWi GR,LWI 83,964 DBPT, 7400,000 ATR,LW! OR,bW1 91,388 G,R,bWI .138,674 DEPT*' 6800*000 ATR*LWi · 6600,000 ATR!,:LWl DEPT'LWl I10;262 6400.000 o..nw GR~LWl. 1t2'.870 6000'000 G,.~,I 80'500 25-HAR-i993 09:56 -999.250 PSR.bWI -999.250 -999.250 PSR.LWI =999'250 3.347 PSR.LWI 3.226 3.209 PSR.bWl 3.235 4.189 PSR*BW1 4.115 5.348 PSR.bWI 4.652 2,615 PSR'bW1 2.745 3,557 PSR,bW1 3.948 3,310 PSR,bWl 3'335 3,740 PSR':bWl 3'586 4'oo : Ps ':bwl 4,632 4,083 PSR'bWl 4~388 2,459 PSR"bWI 3'?i3 1,895 P'$R,SWI 2'i105 2'3t6 PSR'LWt 2~366 ROPE.LW1 ROPE.LW1 ROPE.LWI ROPE.LW1 ROP£.LW1 ROPE.LW1 ROPE'LWl ROp£'LW1 ROPE'LW! ROPE,LW! ROPE*bWI ROPE~Wl ROpE~bWi ROpE'LW1 ROPE'LW! ROPE,L~! PAGEl 15 387,207 295.710 532~370 367'066 233.740 323.397 340'020 450.347 453'183 515'943 592'905 418'798 5551'457 539:'975 484'5?6 477'596 262'655 549'494 chlumber~erAlasRa Co~putln~ Center DEPT, 588~.000 ATR,LWI GR,LW1 .028 DEPT. 5600,000 ATR.LW1 G~.LW1 84.997 DEPT 5400.000 ATR.LW1 GP:[,W1 103,919 DEPT. 5200,000 ATR.LW1 Gm,LW1 98,419 . D~PT, 5000 000 G~,LWI 111~244 DEPT' 4800~000 ATR'LW1 GR.LwI 88'177 DEPT 46ooi~ooo GR~LWX 98,659 ATR'LW! DEPT. 4400=,000 GR,.L:Wt 104,144 ~m~?. 4ooo'ooo GR,Lw1 I02;.:420 DEPT 3800,0 0 ATR'LW D~p~i,, ~6oo.ooo GR'LWI 110,.332 ' D£P?'. 3400.~000 ATR~'LW1 GR,LW1 94,6:23 DEP?.~ 3271Looo .GR;,LWI ' 55,13o 25-MAR-1993 09:56 3.328 PSR.LW1 3.912 3.620 PSR,LW1 3.281 PSR.LWI 3.417 PSR,LW1 3,587 PSR,LWI 3,665 PSR,EWl 3,!67 P'SR'LW! 3.897 PSR,LW! 4'154 PSR,LWX 4,526 PSR*LW1 4,845 PSR':LWI 5,816 PSR'LW1 -999,250 PSR,LWl 3.293 4.891 3.659 3.294 {,4~{ 3.625 3.675 3.362 4.532 4..748 -999'250 ROPE.LW1 ROPE.LWl ROPE.LW1 ROPE,LW! ROPE'LW1 ROPE,LW1 ROPE,LW1 R0PE.LW1 ROPE,LW1 ROPE'bW! ROpE'bWI ROpE'LW! ROPE,LW1 ROP~'LW! PAGEI 16 617,793 614.859 562.937 265.818 612,007 568.414 594,664 488,314 468.003 465'366 '286,872 49~,218 :'999"250 Tape verification Listing chlumberger AlasKa Computing Center 25-MAR-1993 09:56 PAGES 19 **** FILE TRAILER FILE NA~E S EDIT ,003 SERVICE S FLIC VERSION S 001A07 DATE S 93/03/25 MAX REC SIZE S 1024 FILE TYPE S LO L~ST FILE **** FILE HEADER FILE NAME S EDIT ,004 SERVICE S FLIC VERSION S OO1AO7 DATE S 93/0]/25 ~AX REC SIZE : 1024 F!L~ TYPE' : LO LAST FILE FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data ~or each .bit' run ~n 'seParate ~les, BIT RUN NUMBER:. 2- DEPTH INCREMENTS 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH DR 9239.0 LOG HEADER DATA DATE LOGGED~ SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE. (~EMORY OR REA. L-TI~E): TD DRILLER CFT)I TD LOG. GERCFT): TOP LOG INTERVAL (FT), · BOTTOM. LOG. INTERVAL eFT). BIT ROTATIONAL SPE~D HOLE INCLINATION (DEG) MINIMUM ANGLE:~ MAXIMUM ANGLE'S TOOL STRIN~ fTOP~TO BOTTOM) VEN.DO~ TOOL CODE TOOL TYPE CDR RESISTIVITY 9~00-0 '29-0CT'92 FAST 2.3D V4,'OR_ ~EMO.,Y 9800 9239 98oo'i RGS058 chlumberOerAlas)ca Computin0 center 25-MAR-lg93 09)56 PAGE; 18 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE' (IN)I DRILLERS CASING DEPTH (FT)t 8 50 BO~EHOLE CONDITIONS MUD TYPE~ MUD DENSITY (LB/G)I VISCOSITY (S)t MUD PHI MUD.CHLORIDES (PPM)= MAXIMU~ RECORDED TEMPERATURE CDEGF)I RESISTIVITY (OHMM) AT TEMPERATURE(PEGF)I MUD AT MEASURED TEMPERATURE MUD AT MAX CIRCULATING TEMPERATUREI MUD FILTRATE, AT (MT)~ MUD CAKE AT (MT)I LSND 10,30 145"O 2.572 2.372 NEUTRON TOoL MATRIXI MATRIX DEN$ITYI HOLE CORRECTION (IN)I SANDSTONE 65 2§,500 TOOL STANDOFF (IN)I EWR FREQUENCY (HZ),' REMARKS~ RGS READOUT PORT,~TO GR MAD ,PA~$ WASH DOWN'INTER~AL 9172 · -~ 9800' SLIDE ENTIRE WASH DOWN INTERVA. L, SLID:lNG. INDiCATOR NOT PRESENT ON.:.LOG TA~I MAD,.PAS$ APPROXIMAT£L¥ 25 HOURS AFTER DRILLING,: WASH.DOWN DATA SAMPLED :EYERY 10 · SECOND&, DATA. FROM DOWNHOLE ~E~ORY, SOF'TWAR£ 73.0 73.0 DATA FORMAT 8. PECIFICATION RECORD: SET TYPEI- 64EB,..** .. TYPE REPR::CODE VALUE ½ o° 3 73 20 4 66 ! chlumberger Alaska Co~puttnq Center 25-MAR-igc3 09156 PAGEI 19 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 O 66 I ** SET TYPE - CHAN ** NAME EERV UNIT SERVICE APl APl AP! APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE (HEX) DgP? FT 618977 O0 000 O0 0 4 I I 4 68 0000000000 ATP bW2 OHMM 618977 O0 000 O0 0 4 1 ! 4 68 0000000000 PSR LW2 OHMM 618977 O0 000 O0 0 4 I I 4 68 0000000000 ROPE LW2 F/HR 618977 O0 000 O0 0 4 I I 4 68 0000000000 GR LW2 GAPI 618977 O0 000 O0 0 4 I 1 4 68 0000000000 ** DATA ** D~P'Ti,,~ 9800'000 ATR'LW2 -999.:250 PSR.bW2 -999.250 ROpE'LW2 GR:LW2 -999,250 DEPTi. 9600~0 ATP'b"2 3.488 PSR bW2 3'608 ROPE.,L"2 GR.:LW2 97,~ ~8 * DEPT'. 9400:000 A?R'LW= t,62e PSR,~,2 t'93:! ROPE°LW2 GR'LW2 126,4~5 DEPT,GR,~W2 9~'00~'~:4~500 ATR;bW:2' 3.34B PSR,LW2 3'86? ROPE bW2 DBP?~ 9085,000 ATR~L~2 -999,250 PSR,bW2 -999:,~2S0 ROpE°bW2 I24,~ 37 1.80'000 420,407 353'078 '999,250 ** END OF DATA ?ape Verification bistinq chlumber~erAlaska Computing Center 25-~AR-1993 09:56 P AGE: 2O ~*~ FILE TRAILER $~ FILE NAME : EDIT ,004 SERVICE ) FLIC VERSION ) O01AO? DATE : 93/0)/25 MAX REC SIZE : 1024 FILE TYPE : LO **** FILE HEADER. **** FILE NAME ) EDIT ,0o5 SERVICE ) FLIC VERSION : O0~A07 DATE FILE TYPE : LO LAST FILE FIL~ HEADER F!L~ NUMBER 5 RAW MW'D furves and log header data for each bit run ~.n seParate.~les,, BIT.RUN NUMBER:~ DEPTH INCREMENT~ 0,5000 FILE SUMMARY VENDOR TOOL cODE START DEPTH m mm~,mm ~ ~m ~m m ~mm m.m mm m m mm mmmm!mmmmmmm mm 0FTWARE SURFACE SOFTWARE VERSION). DOWNHObE~ SOFTWARE VERSION~ DATA TYPE (MEMORY OR REA5-TI~.E)~,. TD DR~5hER (FT)= TD LOGGER (FT)~ · ; TOP LOG INTERVA~ (FT), ,; BOTTOM. bOG. INTERVAL: (FT)~ BIT ROTATIONAL. SPEED, (RP~): MOLE INCLINATION (DEG) MINIMUM. ANGLE: MAXIMUM ANGLE~ TOOL STRING .(TOP, TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTI¥I~TY 29'0CT-9~ FAST 2,3D V4'O_ MEMORY 92]9,0 3347,o 9239,6 TOOL NUMBER mmmmmmmmm~mmmmm RGS058 IS Tape Veri~ication L~sting chlumberger Alaska Computing Center 25-MAR-t993 09:56 PAGEs 21 8OREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN)S B.500 DRILLERS CASING DEPTH (FT)I 3347,0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10,30 MUD VISCOSITY MUD PHi MUD. CHbORIDES CPPM): FLUID 6088 (C3)S ~AXIMUN RECORDED TEMPERATURE (DEGF~{ 145,0 RESISTIVITY (OHMH) AT TEMPERATURE~DEGF)I MUD AT MEASURED TEMPERATURE [MT)S 2,572 73.0 MUD AT MAX CIRCULATING TEMPERATURES MUD FILTRATE AT [MT)I 2.372 73'0 MUD CAKE AT (MT)I NEUTRON TOoL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION {IN)I 8,500 # TOOL STANDOFF EWR FREOUENCY (HZ)I REMARKSS THIS FILE CONTAINS THE HIGH RESObU?IbN RESISTIVITY DATA, $ bis FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR.CODE VA.~UE I 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 ? 65 I~ 66 36 13 66 0 14 65 FT iS ?a~e Verification bist~nq chlumberqer Alaska Computing Center 25-MAR-1993 09~56 PAGEI 22 TYPE REPR CODE VALUE 15 66 68 16 66 0 66 -** SET TYPE = C~AN.** mmmmmm~mmmmmmmmmmm~m~mmm~mmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmm N~ME SERV UNiT SERVICE API APl APl AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SIMP ELEM CODE (HEX) DEPT FT 618977 O0 000 O0 0 5 1 I 4 68 ATPH 00! OHMM 618977 O0 000 O0 0 5 1 1 4 68 PSP~ 001 OHMM 618977 O0 000 O0 0 5 1 1 4 68 ATER 001 OHMM 618977 O0 000 O0 0 5 1 I 4 68 PSER 001 OHM~ 618977 O0 000 O0 0 5 1 1 4 68 ATV~ 001 OH~M 618977 O0 000 O0 0 5 I I 4 68 PSVR 001. OH~M 618977 .00 000 O0 0 5 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmmm#mmmmmmmmmmmmm~mmm m mmmm,~mmmmmmm~mmmmmmmmmmm~mmmmm~mmmmm*mmmmmm~mm DATA PSER,O01 ' ATVR-O01 DEPT,: 9600.,000 ATPH"O01 PEER*O01 3j582 ATVR'O01 9400' :00 O0 END OF DATA , PEVR,OOi 3. 3 PSVR'O01 PSVR,O01 -581 ' 31'370 ATER.O01 3'63:6 1':898 ATER'O01 1.878 ~3.525 :), :t.697 **** FILE. TRAiLER **** FILE NAME: ) EDIT ,005 VERSION : O01A07 DATE ~ 93/03/~5 MAX R~C,$1Z£ FILE TYPE : LO LAST FILE Tape verification Listin~ chlumberger Alaska Computtnq Center FILE NAME I EDIT ,006 SERVICE ~ FLIC VERSION { 00lA0? DATE ~ 93/03/25 ~AX AEC SZZE { 1024 FILE TYPE ~ LO L~ST FILE ~ 25=MAR-1993 09{56 PAGE~ 23 FILE HEADER FILE NUMBER 6 RAh{ CURVES Curves and log header data for each Pass in separate ~lesl raw background Pass in last f~le P~SS NUMBER; DEPTH INCREMENT~ -,5000 # FILE SUMMARY VENDOR TOOL CODE START.DEPTH mm~mmmm~mmmm~mmm mmmm~mmmmmm HLDT 9710,0 LOG. HEADER~DATA sTOp DEPTH 8800.0 DATE LOGGEDI 80FTWARE VER$IONI TIME LOGGER ON BOTTOMI TD DRILLER (FT)I TD bOGGER(FT)I TOP LOG INTERVAL (FT) BOTTOM LOG {NTERVAL LOGGING SPEED (FPHRI~ DEPTH CONTROL USeD 'TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE HbDT COLLAR bOCATORR HbDT TEbE..ETRY CART XDGE MLDT GAM~A RAY H~DT HLDT CARTRIDGE HbDT HLDT HI VOLTAGE HLDT HLDT SONDE HLDT DOWNHOLE T£LEMETRY H~DT GAMMA RAY SOURCE HLDT NUCLEAR SOURCE $ BOREHOLE AND CASING DATA DR ! LLERS EPT (FT) l LOGGERS CASING DEPTH (FT)~ 03-NOv-92 CP~32,6 2115 03-NOv-92 9800,0 9694,0 8800'0 9690,0 .900,~0 YES TOOL NUMBER CAL-¥. TCC'B"276 SGC-SA-598 MLDC-AA-20 HLDV-AA-19 HLDS-BA-20 rCM-AB-95 GS~-A-226 NSR-F 226 8.500 9785,0 Tape Verification List~nq c~lum~erqer Al~sRe ¢o~putin~ eenter 25'MAR=1993 09:56 BOREHOLE CONDITIONS FLUID TYPEI FLUID DENSITY SURFACE TEMPERATURE (DEGF)I BOTTOM HOLE TEMPERATURE (DEGF)I FLUID SALINITY FLUID LEVEL (FT)I FLUID RATE AT WELLHEAD (BPM)I WATER CUTS (PCT)I GAS/O~L R~TIO~ CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)I MATRIXI MATRIX DENSITYI HOLE CORRECTION (IN)I BRINE 10,20 160,0 SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT)I. BASE NORMALIZING WINDOW (FT)I BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CP8)I FAR:COUNT RATE HIGH SCALE NEAR COUNT RATE bOW SCALE (CP~), NEAR COUNT RATE HIGH'SCALE (CPS)I # TODb'$TANDOFF #' ~EMARK$~ TIED IHTO CET: DATED bOGGED THREE PASSES AT 900 PPH COMPUTING CENTER REMARKSR. THEiHLDT DATA X$ PRESENTED XN THIS FILE. TO, ACCOMPANY THE MWD RE${SIT!~TY, DATA,~ (A$~NO.CDN CORRECTED TO MATCH P~$S [. THEN THE PASSES b'~RE AVERAGED TO YIELD THE DATA PRESENTED HERE,,,, $ LIS FORMAT DATA PAGEI 24 SET.TYPE - 64EB,** TYPE REPR CODE .VALUE 1 66 0 Tape V~r~¢a~on ~st~n~ chlumbetqer AlasKa ComPutlnq Center 25-MAR-1.993 09:56 4 66 5 66 ? 65 66 36 ~3 66 0 14 65 15. 66 68 t6 66 1 0 66 ** SET TYPE - CHAN **- · NAME SERV UNIT SERVICE APl API AP1 APl rIbE NUMB NUMB $lgE REPR PROCESS ID ORDER # bOG TYPE CbA. SS MOD NUMB SAMP EbEM CODE (HEX) DEPT FT 6}8977 O0 000 O0 0 6 1 ! 4 68 0000000000 RHOB HbDT G/C3 6~8977 O0 000 O0 0 6 I I 4 68 0000000000 DRHO .bDT ~] -,~'~977 O0 000 O0 0 6 ! ! 4 68 0000000000 bSRH HbDT 977 O0 000 O0 0 6 1 I 4 68 0000000000 $SRH HLDT G/C3 618977 O0 000 O0 0 6 I I 4 68 0000000000 CCU HLOT V 6%8977 O0 000 O0 0 6 i I 4 68 0000000000 GR HbDT GAP! 6%8977 O0 000 O0 0 6 I I 4 68 0000000000' 25 ** DATA: DEPT'H ~7I~,2!5. CCb. H[DT 3'316 OR*HLDT 2.60 SSR..b~ ~-49S CCb'.b~r ~' G~ . 40O ..b~ 2'~0 SSRH.HbDTDEPT 940i~: 000. RHoB~HbDT 2,240 DRHO'HLD? '0*3.29 DEPT.:. 9200'000 RHOB[HbDT 2,~287 DRHO,HbD? -0:.~ 0 68RH.HLD? 3,558 CCb'HLDT 3.459 GR,HLDT :2*.65 oo2.:ooo t.I o .. 65 GR...HbDT 3.15 $$RH.HbDT 5.57 CCb:~HLDT DEPT' 8800.000 RHOB'HLD? ~::~ 0 GR.HLDT '999'250 SSR,,HLDT 3~:727 CCL.HbDT -99 ? DRHO-HLDT '0'355 bSRH.HbDT bSRH'HbDT bSRH'HLDT bSRH'HbDT :'999.250 2.642 2.569 2':63? 3'094 2'792 IS Ta~e Veri~Ica.t~on 6isting chlumbergerAlaska Computtnc Center 25-MAR-1993 09:56 PAGE: 26 END OF DATA FILE NAME = EDIT ,006 SERVICE : FbIC VERSION : O0 A07 DATE : 93~03/25 MAX REC SIZE : 1024 FIL~ TYPE { 60 LAST FILE : FILE NAME' ~ EDIT °007 , DTE I 03/25 NAX AEC,SIZE : 1024 FILE TYPE I bO 6~$T FILE { FILE HEADER FILE NUMBER 7 RAW CURVES ..... Curves and locj header data for each Pass in separate ftlesl raw background Pass ~n last file PASS NUMBER: I D~PTH INCREMENT{ -.5000 # FIL~ SUMMARY VENDOR TOOL CODE START~DEPTH CNTG 9710.0 $ # A LOG HEADER OAT DATE LOGGEDI SO?TWARE VERSIO~I .,.~. . OTTO. TD DRILLER (FT) I TD LOGGER(FT)I . · o.' BOTTOM LOG INTER,Ab LOGGING, SPEED (FPHR. I~Es/N 11 DEPZ. CONTROL USED ( O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL,,TYPE STOp DEPTH 8997, :0 CP32.:!. 2115 03-N0V'92 9BO0,O 9694.0 B 8 .0 900,0' mmmmmmmmmmm~ Tape vertficetion Llstino chlumberger AlasKa Computing Center 25-MAR-lgg3 09156 PAGEI 27 HLDT HLDT HLDT CNTG HLDT HLDT HLDT HLDT HLDT $ COLLAR LOCATOR TELEMETRY CARTRIDGE GAMMA RAY CNTG SONDE HbDT CARTRIDGE HLDT HI VOLTAGE HLDT SONDE DOWNHOLE TELEMETRY GAMMA RAY SOURCE NUCLEAR SOURCE BOREHObE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT); BDREHOLE CONDITIONS FbUZD TYPEI FLUID DENSZTY SURFACE TEMPERATURE (DE'OF) BOTTOM HOLE TEMPERATURE (DEGF) FLUID SALINITY (PPM) FLUID LE~EL FLUID RATE NATER ~ CUTS GAS/O~b, RATIOI CHOKE (DEG) NEUTRON TOOL TOOL TYPE ( MATRIX ) MATRIX DENSITY HOLE CORRECTION CAL-Y TCC-B-276 8GC-SA-598 CNTG 65 HLDC-AA-20 HLDV-AA-19 HLDS-BA-20 TCM-AB-95 GSR-A-226 NSR-F 226 8,500 9785,0 BRINE 1.60.0 ANDSTONE' .65 BLUEbINE COUNT RATE NORMALI. ZAT~ON IN OIL ZONE 'TOP NORMALIZlN~ WINDOW BASE NORMALIZING WINDOW (FT) I # BLUEblNE COUNT RATE 8CAbE$':$ET BY FIELD ENGINEER FAR. COUNT RATE FAR COUNT RATE HIGH SCALE: (CPS), 5000 NEaR COUNT RATE LOW SCALE (CP$)I~. 0 NEAR COUNT RATE HiGH SCA~E (CPS)I 20000 TOOL STANDOFF (IN)I COMPUTING CENTER REMARK&I THIS FILE CONTAINS PASS ONE OF THE CNTG, LIS FORMAT DATA ?ape Vertficat'~on bist~n.q. ,chlumbergerAlasKa Computing Center 25-HAR-1993 09156 PAGEI 28 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB.** TYPE REPR*CODE VALUE I 66 0 66 0 73 80 4 66 5 66 6 73 ? 65 9 65 F 11 66 12 12 68 13 66 0 14 65 PT 15 66 68 16 66 0 66 1 SET TYPE - CHAN ** mm~m~~mmmm~m~m~m~mm~m~m~mmm~mmmmm~mmmm~mmmmmmm~m~mm~mmmm~mmm~mmm~mmmmm~mmmmm~m~mmmmm NAME SERV UNiT SERVICE ID ORDER # D~PT FT 61 89?7 E~PH CNTG PU 6t8977 ENRA CNTG 618977 CFEC CNTG CPS 618977 CNEC CNTG CPS 618977 R,EFC CNTG CPS 618977 RCE~ CNTG ~S 618977 NPH CNTG 618977 T:NP. CNTG PU 618977 TNRA CNTG 618977 RTNR CNTG 618977 NPO. CNTG PU 6 8977 R~NT CNTG CPS 618977 RCFT CNTG CPS 618977 CNTC CNTG CPS 618977 CFTC CNTG CPS 618977 GP CNTG G.API 618977 CAb! CNTG IN 6i 8977 T~NS CNTG LB 618977 C..bC CNTG V 618977 API APl APl AP1 FILE NUMB NUMB SiZE REPR PROCESS LOG TYPE CLASS MOD NUMB SAMP ELE:M CODE (HEX) mmmmmmemmmmmememmmmmmmmmmmmmemmmmmmmmmmmmmemeeeemmemmemmeemmm ooooo oo o~ , , ~ ..oooooooooo ooooo oo o, , , ~ ~.oooooooooo o o~ , , ~ ~ ooooooooo O0 00 O 7 000000000 00 000 00 0 ? I I 4 68 0000000000 00 000 00 0 7 I I 4 68 00000.00000 O0 000 O0 0 7 1 I 4 68 0000000000 O0 000 O0 0 7 I I 4 68 0000000000 O0 000 O0 0 7 1 1 4 68 0000000000 00 000 O0 0 7 1 ! ~ 68 0000000000 O0 000 O0 0 7 I I 4 68 0000000000 O0 000 O0 0 7 I ! 4 68 0000.000000 c~om~eroer Alaska co~potl~.q Center DEPT.. 9710.000 CHE~.CNTG 2418.755 RCEF.CNTG TNPH,CNTG 40,I~6 TNRA,CNTG RCNT.CNTG 1015,476 RCFT.CNTG G,.CNTG 65.000 CALI.CNTG D,PT. 9600!~00. ENPH'CNTG C,E~.CNTG 25 ~ 07 RCEF.CNTG TNP,.CNTG ~ 23 TNRA.CNTG ¢.:C.TG 60:375 C~LZ.CNT~ DEPT, 9400.000 ENPH'CNTG TMPH,CNTG. .636 TNRA,CNTG ~CNT,CNTG 955.'~ Il RCFT,CNTG G~.CNTG 68 ~50 . CNEC'CNTG 2530,329 RCEF, CNTG TNPH-CNTG 33,859 TNRA~CNTG RCNT.CNTG 994,193 RCFT'CNTG GR.CNTG 132.500 CAbI'CNTG CNEC*CNTG 8,256 RCEF-CNTG TNpH,CN. TG, 32-~74 TNRA,CNTG RCNT,CNTG 1068'959 RCFT,CNTG GR,CNTG 76':3~3 CASI-C~TG F~E~ NANE {. EDIT~ ,007 SERVICE ~ F~ICi V~R$ION [ 00lA0? DATE: ~ .. : 93/03/25 MAX. REC, $'IZE' = 1024 FIbE TYPE ~ LO LAST FILE : 25-NAR-1993 09:56 58.741 ENRA.CNTG 7.088 342.~13 RCEN.CNTG 2239.475 3.987 RTNR.CNTG 4.292 , .ooo 461 017 RCEN,¢NTG 2353.39 3:451 RTNR,CNTG 3.851 6.105 TENS.CNTG 387 O0 47,970. ENRA.CNTG 6.288 394.62 RCEN, 4,01~ CNT~ 2198.967 RTNR-CNTG 4.460 229 ~2 CNTC'CNTG. 9'40,420 6:I_ 5 TEN$,CNTG- 3.520.000 45.972 ENRA'CNTG 6'127 411,997 RCEN".CNTG 2314.,474 3.519 RTNR,CN~G 267.580 CNTC-CNTG 988,334 6,117 TENS.CNTG 3675.000 39.237 ENRA,CNTG 5'550 495,694 RCEN,CNTG 2568-929 441 RTNR,iCNTG 3..765 3t{:528 CNTC,:CNTG 1079.408 ,333 TENS.,CNTG 351:0'000 CFEC.CNTG NPHI.CNTG NPOR.CNTG CFTC.CNTG CCL.CNTG CFEC'.CNTG NPHI,CNTG. NPOR.CNTG CFTC.CNTG CCL.CNTG CFEC,CNTG NPHI,CNTG NPOR.CNTG CFTC,CNTG CCLoCNTG CFEC~CNTG~ NPHI.CNTG NPOR.CNTG. CFTC,CNTG CCL,CNTG: CFE¢'CNT¢, NPHI,CNTG: NPOR-CNTG CFTC-CNTG CCL,CNTG~ PAGE~ 29 341.245 47.1~2 40,1 6 027 439,432 37.339 31,472 024 371,750 47,576 40.315 240.896 0.032 38,575 34.004 28~.765 -.,037 5oo'5e2 37':157 31 ~ 47 .-0.04I chlumberger la.sKa Corn utinq Center 25-MAR-1993 09156 30 **** FILE HEADER **** FILE NAME ~ EDIT .008 SERVICE ~ FLIC VERSION : 001A07 DATE ~ 93/03/25 MAX AEC SIZE I 1024 FILE TYPE : LO LAST FILE I FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header eata ~or each Pass tn separate ~iles; raw background Pass tn last PASS NUMBERI 2 DEPTH INCREMENTl --5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 97 $ LOG HEADER DATA STOP DEPTH 8991,0 DATE bOGGEDI SOFTWARE VERSION, TIME LOGGER ON BOTTO", TD ORIbbE. CF,){ TD bOGGER(FT). !IT ' TOP bOG INTERVAL BOTTOM bOG INTERV (FT) I TOOL STRING CTOP TO BOTTOM) VEN.DOR TOOL CODE TOOL TYPE HLDT HLDT HLDT CNTG HLDT HLDT HLDT HLDT HLDT HLDT $ COLLAR bOCATOR TELEMETRY CARTRIDGE GAMMA RAY CNTG SONDE HbDT CARTRIDGE'_ HLDT HI. VOLTAGE HLDT SONDE _ ~ DOWNHOLE TELEMETRY GAMMA RAY. SOURCE NUCLEAR SOURCE: ~OREHObE A~P CASING DATA OPEN H:ObE BIT SIZE LOGGER8 CASING DEPTH (FT) 03-.NOv'92 9800..0 9694.0 8800'0 9690'0 900.'0 :TbOb NUMBER CAb-Y TCC-B'276 ;SGC-$A-L98 · CNTG 65 HLDC-AA'20 HLDV-AA-19 HLDS-BA-20 TCM-AB-95 GSA-A-226 'NSR=F 226 8.500 9785.0 c~lu~er~er Al~s.~ Computtnq Center ,, 25oMAR=J993 09:56 PAGE~ 31 EMOLE CONDITIONS FLUID TYPE~ FLUID DENSXTY CLB/G)~ SURFACE TEMPERATURE (DEGF)~ (DEGF)~ BOTTOM HOLE TEMPERATURE FLUID SALINITY (PPM)I FLUID LEVEL (FT))ADE FLUID RATE AT WELLH (BPM WATER CUTS (PCT)~ GAS/OIL RATIOS CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)I MATRXX~ MATRIX DENSXTY~ HOL~ CORRECTION tIN): BLUELINE COUNT RATE NORMALIZATION IN TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW ~LUELINE COUNT RATE $CA~E$ SET BY FIELD F'AR COUNT RATE LON SCALE 'FAR COUNT RA'TE HIGH SCALE NEAR COU.T RATE ~OW $CA~E (CP~ NEAR COUNT RATE HIGH: SCALE{ (CPS)~ # TDOL: sTANDOFF RE~ARK$~ BRiNE 10,20 160.0 SANDSTONE 2.65 ZONE 0 ooo 0 20O00 ,COMPUTING CENTER REM'ARK$~ .. THiS FiILE CONTAINS PASS TWO OF THE CNTG,:: $ FORMAT SPECIFICATION RECORD ** SET TYPE -.-6¢EB TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 80 4 66 ,IS Ta~e Verification Listinq chlumberqerAlaska Computin~ Center ... 25-MAR=t993 09~56 PAGE~ 32 TYPE REPR CODE VALUE 7 65 9 65 1! 66 12 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** mm~mmMMm~mmmlmmmmmmm~m~m~mmmmmmmmmmmmmmmm~. ' . NAM~ SERV UNIT SERVICE APl APl APl ID ORDER # LOG TYPE CLASS mmmmmmm~mmmmmmmmmmmmmmmmm~m~w~mmm~mmI~mm API FILE NUMB NUMB SIZE REPR PROCESS MOD NUMB SAMP ELEM CODE (HEX) 0 ~ 1 I 4 68 0000000000 0 $ ! I 4 68 0000000000 0 8 1 I 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 ! I 4 68 0000000000 0 ~ 1 1 4 68 0000000000 0 ~. I ! 4 68 0000000000 0 8 1 ! 4 68 0000000000 0 8 ! I 4 68 0000000000 0 8 1 ! 4 68 0000000000 0 8 I I 4 68 0000000000 0 8 1 I 4 68 0000000000 0 8 I 1 4 68 0000000000 0 8 1 I 4 68 0000000000 0 8 I 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 t 4 68 0000000000 0 8 I I 4 68 0000000000 0 8 I 1 4 68 00'00000000 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 97021'000 ENPH,CNTG., 42i*T27 CNBC,CNTG 2297',465 RCEF,CNTG 393,,324 TNPH,C'NTG 72,895 TNRA~CNTG 5:'0~4 RCNT,CNTG !069,063 RCFT,CNTG 200,7 :~ G~.CNTG 7~,.250 CALI'CNTG 5,836 F~NRA'CN?G R~N '¢NTG RTNR,CNTG CNTC':CNTG TENS, CNTG 212:7.171 5 :' 273 1059'0~9 1800.000 7 .836 3 864 068.566 NPOR~,.CNTG. CFT'C;~CNTG CCL,CNTG ? CFBC CNTG NPHI, CNTG. NPOR. CNTG CFTCCNTG 36~,. 843 7 ,'895 21~,9!t -0.027 3 !. 032 314.353 ch].umberqer Al~$ka Co~put~ng Center GR'CNTG D~PT. CNEC.CNTG TNPH.CNTG RCNT.CNTG GR.CNTG DEPT CNEC:CNTG RCNT.CNTG GR.CNTG DEPT. CNEC.CNTG T~PH,CNTG RCNT.CNTG G~.CNTG DEPT.:~ CNEC,CNTG TNP~.CNTG RCNT,CN?G. 66.688 2329.540 36.563 891.573 73-000 9200'000 2544,034 37.706 994.641 1~1.125 90001000 10891531 71 063 8990,1,500 .451 1030,406 112o250 CALI.CNTG ENPH'CNTG RCEF.CNTG TNRA'CNTG RCFT.CNTG CALI.CNTG ENPH.CNTG RCEF.CNTG TNRA'CNTG RCFT-CNTG CAbI.CNTG ENPH.CNTG RCEF,CNTG TNRA.CNTG RCFT.CNTG CAbI.CNTG ENPH~CNTG RCE:F'CNTG' TNRA,CNTG RCFT,CNTG CALI.CNTG ,,. END..Or DATA 25-1~AR-1.993 09156 6.129 48.018 381.678 3.900 233.947 6. 152 45 27 3.878 238.308 6.14! 40 O89 779 46~ 381 325 :I18 6 .148 42.7_03 484.372 · 3; 805 250'288 6,152 TENS.CNTG ENRA.CNTG RCEN.CNTG RTNR.CNTG CNTC.CNTG TENS.CNTG ENRA.CNTG RCEN.CNT~ RTNR.CNTG CNTC.CNTG TENS.CNTG ENRA.CNTG ~CEN.CNTG ~TNR.CNTG CNTC.CNTG TENS.CNTG ENRA'CNTG. E~.CNTG CNTC*CNTG TENS.CNTG 3740.000 6'292 2135.347 4.196 920.03O 3390.000 6.050 474 2311:797 982.730 3390.000 5.626 1095.766 3285.:000 5.854 2491.957 883 3145.000 CCL'CNTG CFEC'CNTG NPHI.CNTG NPOR.CNTG CFTC.CNTG CCL.CNTG CFEC.CNTG NPH~.CNTG NPOR.CNTG CFTC.CNTG CCL.CNTG CFEC.CNTG NPHI.CNTG NPOR.CNTG CFTC..CNTG CCL.CNTG CFEC..CNTG, NPMIoCNTG NPOR.CNTG CFTC.CNTG CCL.CNTG PAGE= 33 '0.049 38'356 041 420,532 45,123 37,591 263,45~ =0.03 484.997 29. 458.323 43.794 '37,329 214,000 .'0.045 VERSION : 001 DATE = 93/03/25 NAX AEC $~ZE = !024 FILE TYPE bAST FILE FILE. NA~E: I ED'IT' .009 $~RVICE. = FbIC'~ VERSION = O0!AO7 DATE = 93/03/25' ~AX AEC'SIZE: : 1024 FILE TYPE I bO NUMBER g IS Ta e Vert~tcation bist~nq chlum~erqer Alaska ComputlnH Center 25-MAR-1993 09:56 PAGEI 34 RAW CURVES Curves and log pASS NUMBER~ DEPTH INCREMENT{ FILE SUMMARY VENDOR TOOL CODE CNTG #. header data for 3 '.5000 START DEPTH mmm~mmmmmmm 9703,0 each HEADER. DATA DATE LOGGEDI SOFT~ARE YERSION) ~ . TI~E LOGGER ON BOTTOMI TD DR~LLER (FT)I TD 5OGGER(FT)) TOOL STRING~ (TOP TO VENDOR TOO~ CODE mmm~m~m~mmmmmm HbO? HbDT HLDT C~TG H~DT HLDT H, LDT H~DT HLDT HLDT $ BOREHObE AND CASING DATA OPEN 'HOLE BIT SIZE (~N)~ DRILLERS CASING DEPTH LOGGERS CASING DEPTH ~OREHObE CONDITIONS BOTTOM) TOOL TYPE :ObbAR bOCA. TOR_. ELEMETRY CARTRIDGE GAMMA R~Y CNTG SO DE HbDT CARTRfDGE HLDT HI VOLTAGE HbDT SONDE DOWNHOLE TELEMETRY GAMMA RAY SOURCE NUCLEAR SOURCE FLUID TYPEI F~UID DENSITY (LB/G)I SORFACE T.EMPERATURE (DEGF)I BOTTOM HOLE TEMPERATURE FLUID SAL~NIT'Y FLUID EVEL (FT){ FLUID RATE AT WELLNEAD wATER CUTS (PCT){ GAS/OIL RATIO{ Nfu?RoN pass in separate'~tles) raw STOP DEPTH . 8796,0 03-NOV-92 CP ~2.6 211 03-NOV-92 9800,0 9694.0 8800,0 9690,0 900,0 YES TbOb NUMBER CAL'Y TCC~B~276 SGC'SA-598 CNTG:65 HhDC-AA-20 HLDV-:AA-19 HLDS-BA-20 TCM-A,B-95 GSR-A-226 NSR-F 226 9785,0 BRINE 10,20 160,0 background PaSS in last file IS ?ape Verification bistinq chlumberqer Alaska Computing Center 25-MAR-1993 09:56 TOOb TYPE CEPITHERMAL OR THERMAb): MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): BbUEbINE COUNT RATE NORMAbIZATION IN OIL zONE TOP NORMALIZING WINDOW (FT)I BASE NORMAbIZING WINDOW (FT)I BLUELINE COUN?RATE SCALES $£? BY FIELD ENGINEER FAR COUNT RATE LOW $CAL£ CCPS): 0 FAR COUNT RATE HIGH SCALE (CP$): 5000 NEAR COUNT RATE HIG. SCALE (CPS)= 20000 TOOb STANDOFF (IN)= # REMARKS= TIED INTO CBT DATED LOGGED THREE PASSES AT 900 ~PH COMPUTING CENTER REMARKS= THIS FIbE CONTAINS PASS THREE DF THE CN?G, $ PAGE= 35 **..DATA FORMAT SPECIFICATION RECORD SET T~PE - 64EB ** .:TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 80 4 66 5 66 6 73 7 65 9 65 1! 66 12 12 68 13 66 0 14 65 FT 15 66 68 ~6 66 66 IS Tape Veri~tcation ~ist~nq chlumberqer AlasKa Co,put,nc3 Center 25-MAR-1993 09:56 PAGE~ ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 APl AP1 APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS NOD NUMB SAMP ELEN CODE (HEX) ,~,~ r~s~,o~ oo ooo oo o ~ t ~ 4 so oooooooooo ~.~. ¢.~ ~ s~,~ ooooo oo o ~ ~ ~ 4 6~ oooooooooo ENRA CNTG 618977 O0 000 O0 0 9 ! I 4 68 0000000000 cr~c c,~ c,s s~,~ ooooo oo o ~ , ~ 4 s~ oooooooooo c,~c e.~ cps s~~ oo ooo oo o ~ ~ ~ 4 s~ oooooooooo .¢~r c,~ c,s s~~ oo ooo oo o ~ ~ ~ 4 ss oooooooooo .c~. c.~ c~s s~,~ ooooo oo o ~ ~ ~ s s~ oooooooooo ,,,~ e,~ ~ s~,~ ooooo oo o , ~ , s s~ oooooooooo ~... e.~ .us,,.~ oo 000 oo 0 . ~ ~ 4 s, 0000000000 · ..~ ¢.~ s,,~ oo000 oo 0 . ~ ~ 4 so 0000000000 ,~.. C.T~ s,,,~ oo 000 oo 0 . , , , s0 oooooooooo ..o.e.~ ..s,,.~ oo ooo oo o , ~ , 4 so oooooooooo ReNT CNTG CPS O0 000 O0 0 9 ! ! 4 68 0000000000 s~~ oo o o oo o ~ ~ ~ s s~ oooooooooo CNTC CNTG CPS 61~977 O0 000 O0 0 9 I 1 4 68 0000000000 CFTC CNTG CPS 618977 O0 000 O0 0 9 1 I 4 68 0000000000 ~ c.?~ ~ 6~977 oo ooo oo o ~ t I ~ s~ oooooooooo c~ ~ c~ x. $~977 ooooo ooo ~ i ~ 4 s~ oooooooooo EN$ ONTO LB 618977 O0 000 O0 0 9 I I 4 68 0000000000 CL CN~ v s~s~? oo ooo oo o ~ 1 ~ 4 ss oooooooooo DATA CNEC.CNTG TNPH.CNTG RCNT.CNTG GR.CNTG NEC CNTG TNPH CNTG ReNT CNTG GR CNTG DEPT CNEC CNTG TNPH CNTG ReNT CNTG G~ CNTG DEPT.. CNEC,CNTG TNPH.CNTG ReNT CNTG GR:CN. TG 9703 00.0 2335 871 43. 815 1062 665 74 375 9600 000 10'/8 4~ 62 ~50 9400,000 2O7 69- oloo'ooo 2533,, .,I 33 36.435 963,206. 137,000 ENPH..CNTG 46..~96 ENRA,.CNTG 6.~_94 RCEF,CNTG 378'058 RCEN,CNTG 2162,~30 TNRA,CNTG 4,~00 RTN'R,CNTG 4. 17 ,34'9 CNTC,CNTG 1052 RCFT.CNTG 23~ c~.~.c..~.,~, ~,s.c~ ~,~o.~ EN'PH.CNTG 40. 70 RCEF,CNTG 440,~ ENRA. CNTG 34 RCEN'CNTG TNRA,CNTG '3~5.19 RTNR,CNTG RC'FTi;rCNTG 29~.:492 CNTC'CNTG CALI.CNTG 7133 TEN$,CNTG ENPH CNTG RCEF CNTG TNRA dNTG RCFT CNTG CALI CNTG ENPH.CNTG RCEF~ CNTG TNRA,CNT~ RCFT:s CNTG CALI..CNTG 400 229 16 6 i~56 44 041 41569i31 2535 4 8 6 148 ENRA~,CNTG RCEN,rCNTG ,CNTG RTNR ?£N$ EffRA,CNTG RCEfl.CNTG RTNR ,CNTG CNTC,CNTG TENS.CNTG 5 686 ~403 233~ .390 6.:145 221~.014 .511 904.876 3710'000 5 968 ~8 3285 60~ CFEC.CNTG NPH[:.CNTG NPOR.CNTG CFTC.CNTG CCL-CNTG C'FEC.C~TG NPHI.CNTG NPOR.C~TG CFTC'CNTG CCG.CNTG CFEC~CNTG NPHX,CNTG NPOR,CNTG CFTC,CNTG CCLoCNTG CFEC.CNTG NPHI,CNTG NPOR.CNTG CFTC:.CNTG CCL.CNTG 377100 oo! 815 257. 547 0 438,923 '38;577 .34~062 307.686 '0o'050 387',337 48,'082 41',578 229.829 0,05.3 424,502 40,617 ,3~,.063 980 36 chlu~ercjer Al~sl(8 Co~ut~n~ ~e~ter 25-MAR-1993 09:56 PAGE: 37 DEPT, 9000.000 ENPH,CNTC CNEC,CNTG 2693,435 RCEF.CNTG TNPH.CNTG 30,816 TNRA.CNTG RCNT,CNTG 1064,959 RCFT.CNTG GR.CNTG 72.875 CALI.CNTG DEPT~ 8800,000 ENPH,CNTG CNEC..CNTG 2870,030 RCEF.CNTG TNPH,CNTG 29,349 TNRA,CNTG RCNT.CNTG ~81,500 RCFT.CNTG GR.CNTG 67,658 CALI.CNTG DEPT' 87 ,500 ENPH'CNTG RCNT:CNTG t[64,704 RCFT,CNTG GR.CNTG 78.3t3 CALI.CNTG 36,986 EN~A CNTG 498.228 RCEN:CNTG 305 69 CNTC.CNTG 6.172 TENS,CNTG 34.153 ENRA,CNTG 575,946 RCEN,CNTG 3-274 RTNR,CNTG- 314,'823 CNTC,CNTG 6.~56 TENS.CNTG ~:695 ENRA'CNTG 5 616 RCEN,CNTG 30~.479 RTNR,CNTG ,:118 CNTC,CNTG 6-~52 TENS,CNTG 45:344 CFEC,CNTG 253 461 NPHI.CNTG 3.533 NPOR.CNTG 1085.182 CFTC.CNTG 3300.000 CCL.CNTG 5~076 2730,068 72 3'~79 1140. 3285.000 CFEC.CNTG NPH[,CNTG NPOR,CNTG CFTC.CNTG CCL.CNTG 5~ CFEC;CNTG 2642."~)~ NPHI,CNTG 3~,.7.7t NPOR CNTG 1125'754 CFTC CNTG 3245,000 CCL CNTG~ , 503,972 37.283 3~,915 32 .499 0.036 107 35 ~22 0.061 545'488 37,858 679 END OF' DATA *'*** FILE TRAIL:ER **** FI.LE' NAME. : EDIT ,009 SERVICE. : FLIC VERSION : 00,1A07 DATE : 9.3/03/25 MAX AEC ,SIZE' : 1024 FILE;TYPE: : LO L~ST FILE: I ***,~ TAPE:TRAILER SERVICE NAME: : EDIT DATE: : 93/03/25 oSI¢IN : FLhtC TAP~ NAME : 92640 C'~NTINUATION # : i PREVIOUS'TAPE CO~NENT : ARCO AhASKA, INC'i, KUPARUK RIVER UNIT,2M~DI,50~lO!3-20185'O0 **** REEL TRAILER: **** S'ERVICE NAME : EDIT D. TE~ : 93/03/25: ORiO~N : FbIC R. EEL.: NAME .,. : 92640 CONTINUATION # : PREVIOUS REEL : COMMENT ~ ARCO ALASKA, iNC':,KUPARUK RIVE~ UNIT.,2M"O1,50'~03-20185'O0 ALASKA COMPUTING CENTER *-'----- SCHLUMBERGER '-'''--~ COMPANY NAME = ARCO AL:ASK~ ZNC, WELL NA~E., = 2M-01 FIELD NAME I KUPARUK: RXVER BORouGH ' = NORTH SLOPE STATE :ALASKA AP! NUMBER ~ 501032016500 REFERENCE NO : 92640 RECEIVED DEC 0 ? !$ Tape Verification bistinq chlumberqer AlasKa ¢omputlnq Center 25-NOV-1992 07:11 SERVICE NAME : EDIT DATE : 92/11/25 ORIGIN : FLIC REEL NAME : 92640 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA, INC,,KUPARUK RIVER UNIT,2M-OI,BO-103-20185-O0 **** TAPE HEADER SERVICE NAME : EDIT DATE : 92/11/25 TAPE NAME : 92640 CONTINUATION # : ! PR£VIOU$ TAPE COMMENT ) ARCO TAPE HEADER KUPARUK RIVER UNIT MWD/MAD BOGS # WELL NA. ME) AP! NUMBER) OPERATOR~ LOGGING COMPANY: TAP~ CREATION DATE) # 8UR,'ACE LOCATION 'SECTiON~ TOWNSHIP: RANGE: F'W~: ELEVATION(FT FRO~ ~$L 0) K~bt¥ BUSHING: D~RR~CK FLOOR: GROUND LEVEL: WELL CASING RECORD M-O1 01032018500 A~CO ALASKA. INC. WEbb V lST STRING 2ND STRING BIT RUN ! BIT RUN 2 BIT RUN 3 92640 92:640 LEVAD ~ LEVAD 27 11N 8E 114 147.00 147.00 !06 00 OPEN HOL~ CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9,625 3347,0 Tape Verification t,.istinq chlumberger Alaska Computing Center 25-NDV-199~ 07:11 3RD STRING PRODUCTION STRING ~EMARKSI FIELD ENGINEER'S REMARKS: ********** RUN ! RGS READOUT PORT TO RESISTIVITYTu BiT: 65~6' DRILLED INTERVAL: 3347 - 9239', *******~,~ RUN 2 RGS READOUT PORT TO G~ TO BIT: 36.5'. · RESISTIVITY TO BiT: ~6,0' MAD PASS WASH DOWN INTERVAL 9172 ' - 9800' SLIDE ENTIRE WASH DOWN INTERVA~ SLIDING INDICATOR NOT PRESENT.~ bOG TAB: ~AD PASS APPROXIMATELY 26 HOURS AFTER DRILLING. WASH DOWN DATA SAMPLED EVERY SECONDS. DRILLING DATA SAMPLED EVERY SECONDS, DATA FROM DOWNHOLE MEMORY. SOFTWARE V2.3D/4.0C $ $ **** FILE HE~DER FILE NAME : EDIT .001 SERVICE : Fb!C YERSlON : 00!A07 DATE : 92/~/25 MAX AEC SIZE I 1024 FILE TYPE LAST FILE PAGEI FILE HEADER FILE NUMBER: EDITED ~ERGED MWD _ Depth shifted'and Cl~pped curves; all bit runs merged. DEPTH'INCREMENT 0,5000 FILE SUMMARY KRU TOOL CODE START DEPTH 8TOP DEPTH ~WD 3347,0 9800,0 ~ASEbINE CURVE FOR SHIFTS~ GE CURVE~ SHIFT DATA ¢~EASURED DEPTH) BASELINE DEPTH 9602~0 9597,5 IS Tape Verification Listing cblumberger Alaska Computing Center 25-NOV-1992 07=11 9570 9512 9506 9488 9485 9439 9376 9323 9305 9294 928 927~ 9249 9214 9166: 9164 91 0120 9093 9O8] 9062 9047 0 8988 8856 872~ 10 9567.0 9507.5 9502,0 9483.5 9481.5 9436.5 9]74.0 9346.0 9320.0 9302,0 9291.0 9280,0 9268,5 9244.5 9209,0 9161,0 9159,0 9157,0 9133,5 9117,0 9108.5 9090.0 9080,5 9059'0 904].0 9035.0 9014.5 8984,5 8852,0 8719,5 95,5 M~R~ED DATA SOURCE .'AU TO0~ CODE ~MARKS BIT RUN NO, MERGE. TOP 1 3347,0 2 9239,0 MERGE BASE , 9239.0 9800,0 THE DEPTH SHIFTS ABOVE REFLECT MWD GR TO CASED HOLE GR FROM CET~CBT RUN ON 0]-NOV..92- ' ~ER WOLCOTT, ALL OTHER CURVES WERE CARRIED WITH THE GR SHIFT, THE CURVE NAMES FOR THE SAMPDING TICKS ARE RTCK (RG$) & 'GTCK (GR),i THE SAMPLIN~ TXCK~ ~HAT APPEAR iN THIS FiLE ARE SAMPLED AT -5 FT-- HOWEVER, THE ACTUAL SAMPLE RA~E IS A VARIABLE RATE. THE SECOND FI. SE WI55 CONTAIN THE TICKS AT ,1FT SAMPLING WHICH WILL MORE ACCURATELY REPRESENT THE FIELD DATA, ***** WASHDOWN DATA ONbY_F~O~ ~239' TO 9800', ***** MAD PASS APPROXIMATELY 25 .OUR AFTER DRILLING., $ $ fORmAT DATA IS Ta~e Verificatio~ c~lu~ber~er ~las~a Co~utin~ Center 25-NOV-1992 07:11 FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64E5 66 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 12 68 13 66 ~4 65 15 66 16 66 O' 66 0 36 1 0 68 1 0 ** SET TYPE - CHAN ** ID ORDER # bOG TYPE CLASS MOD NUmB SAMP E~EM CODE (HEX) DEPT FT 618977 00 000 00 0 1 I 1 4 68 0000000000 RTCK MWD $ 6~8977 00 000 O0 0 I I ! 4 68 0000000000 GTCK MWD S 618977 00 TAB NWD HR 618977 O0 RA MWD OHNM 618977 00 R~ NWD OHMM 618977 O0 R0P ~WD F/HR 61~977 00 GR ~WD GAPI 618977 O0 SNR ~WD DB 618977 00 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 i I 1 4 68 0000000000 4 68 0000000000 000 O0 0 1 I 1 000 O0 0 I I 0000000000 000 O0 0 1 ! I 4 68 O0000000OO 000 O0 0 1 ! I 4 68 0000000000 000 O0 0 ! t ! 4 68 .0000000000 DEPT SNR,MWD DEPT, RA,MWD SNR,~WD 9795,500 '999.'250 "999,250 "999.2.50 '999,250 '999.250 0,:: 35 IS ?a~e Verification bisti~a chlu~herger AlasKa ¢o~pu~ing Cen~er DEPT, 9400,000 RTCK,MWD R&.MWD i,?2B RP,~WD SNR,MWD '999,250 DEPT, 9200,000 RTCK,MWD RA,MWD 3.417 RD,MWD SNR,MWD '999.250 DEPT. 9000.000 RTCK.MWD RA.MWD 3.199 RP.MWD SNR.MWD 529.659 DEPT.- 8800.000 RTCK.MWD RA.MWD 3 245 RD.MWD SNR.MWD 514:707 DEPT. 8600,000 RTCK.MWD RA.,WD 4 164 SN' ;MWV 510:250 DEPT, 8400,000 RTCK.MWD DEPT,==. 8200.000 RTCK.MWD RA,MWD 2.585 RP'MWD 8NR,MWD 480,250 DEPT,, 8000.000 RTCK,MWD RA,MWD 3'800 SN~;~WD 463:'700 DEPT. 7800,000 RTCK.MWD DEPT 7600,000 RTCK,MWD R :'WO 3.5 2 $N~.MWD 498;700 DEPT, W 7400,000 RTCK,MWD R~'~D 4 ~'298 RP"MWD SNR,MWD ~i69,400 DEPT, 7200.000 RTCK.MWD RA,MWD ' 3-909 ~P.MWD $NR,MWD 4~8,550 DEPT'. 7000,000 RTCK,MWD SN~,MWD 406, $0 25-NOV-1992 07:11 'g99.250 GTCK,MWD 1.915 ROP,NWD '999.250 GTCK,~WD 3.486 ROP,NWD '999.250 GTCK,~WD 3.188 POP.MWD -999.250 GTCK,MWD 3,281 ROP,MWD '999.250 GTCK,MWD 4.016 . 000 GTCK.~WD .929 ROP,~WD 1,~0 GTCK.MWD 2. 5 ROP,MWD~ GTCK,MWD 1, CK MWD ROP.MND 1.0~0 GTC~,MWD .1 9 ROP':MWD -999.250 3'320 ROP.~WD -999.250 GTCK,MND 4.453 ROP.MWO . 3 ROP;MWD -999.250 457,984 1.000 294.168 !.000 334.199 -999.250 461.438 1.000 286.163 -999,250 294.552 99,250 '~35.262 -999,25~0 472,030 i'.ooo 600'024 -999,250 512,554 .000 57 .631 t 0 15 .999'~50 567,265 TAB,~WD GR,~WD TAB,MWD GR,~WD TAB,MHD GR,MWD ?AB.~WD GR,MWD TAB.~ND GR.MWD TAB,MWD GR.MWD ~AB,MWD GR,MWD TAB,MWD TAB MWD GR:MWD TAB,M~D GR'MWD TAB,MND GR..~WD TAB,MWD GR,NWD TAB.MND GR'MWD PAGEI 0,064 122,656 64 0.714 117,695 0.405 1t8,484 0 252 111~626 0,61 105,01 0,?~9 111,330 112, 1 ,707 't28,650 0'153 137,491 Tape Verification Listing chlumbergerAlasKa Computing Center DEPT, RA MWD 8NR~MWD DEPT, R~ MWD D~?. R~.MWD SNR.MWD D£PTo R~.MWD 8NR.MWD RA MWD SNR~MWD DEPT.M SNR'MWD DEPT'~ R.MWD DEPT,MwD 8NR.MWD DEPT .RA:MWD 8NR~MWD D~?o ~,MWD ~N~,MWD RA'MWD SNR'MWD RA'MWD 8NRoMWD RA,MwD 8NR,MWD 6800,000 2.148 412,900 6600.000 1.870 389,200 6400,000 2 )6 : 0o 6200.000 2.150 373,B00 6000,000 41._ 950 s o :ooo 464 410.850 000 560~'.385 5400'000 5200.000 37 300 5000,000 3.347 342"450 4800.000 3.629 323'750 4600.000 3,.800 300;~50 4400,000 3 556 278 250 RTCK.MWD RP.MWD RTCK.MWD RP.MWD 25-NOV-1992 07:11 1.000 GTCK.MWD '999.250 GTCK.MWD 2,021 ROP,MWD -999.250 540.012 1.000 553.864 RTCK.MWD -999.250 GTCK.MWD -999.250 RP.MWD 2.282 ROP,MWD 49"/'2 90 RTCK.MWD RP.MWD RTCK.MWD RP.MWD RTCK MWD RP:MWD RTCK.MWD RP.MWD RTCK.MWD RP,MWD RTCK,MWD RP.MWD RTCK,MWD RTCK'MWD 'Rp. MWD -999.250 GTCK.MWD 2.297 ROP,MWD 1.000 GTCK,MWO 3.287 ROP.MWD -99~,0250 GTCK,MWD , 69 ROP,MWD "99~,~0 GTCK',MWD , 8 ROP,MWD , ROP,MWD .ooo · 223 ROP,MWD GTCK,MWD ROP,MWD GTCK,MWD ROP'MWD GTCK,MWD ROP,MWD GTCK,MWD '~OP;M'WD , 5O '999-~245 RTCK,MWD RP,MWD RTCK,MWD RP; ~WD 1.000 248.053 -999.250 581.842 -999. 595'6250.77 1. 000 629'489 1.000 554.320 -999,250 388~647 '999.,250 618,442 '999'250 555'457 -999 !250 62 :s 3 '999.250 '518.71:0 TAB.MWD GR.~WD TAB.MWD GR.MWD TAB.MWD GR .MWD TAB.MWD GR.MWD TAB,MWD GR.MWD TAB,MWD TAB.MWD TAB,MWD GR,MWD .TAB WD ?AB'M~D GR,MWD ?AB'MWD GR.MWD TAB'.MWD GR'MWD TAB,MWD GR,MWD PAGE: 0.454 155.041 390 0,311 124,799 0.307 104,800 0.289 79.429 0.168 81,718 760 0'195 104 · 720 0,289 .523 Tape Verification l, isting chlumbergerAlasKa Computing Center DEPT, 4200,000 RTCK,MWD RA,MWD 3,932 RP.~WD SNR.MWD 316,350 DEPT, 4000,000 RTCK.MWD RA MWD 3,961 RP,MWD DEPT. 3800.000 RTCK.MWD RA.MWD 6.023 RP.MWD SNR,MWD 322,400 25-NOV-1992 07:11 -999.250 GTCK,MWD 3.929 ROP.MWD -999,250 GTCK,MWD 3.916 ROP,MWD 1,000 6.090 DEPT. 3600,000 RTCK.MWD -999.250 RA MWD 4.712 RP,MWD 4.523 SNR:MWD 328,950 DEPT. 3400,000 RTCK.MWD -999-250 R~.MwD 5.558 RP,MWD 5.504 SNR.MWD 352,450 END O~ DATA GTCK,MWD ROP,MWD GTCK.MWD ROP.MWD GTCK,MWD RDP,MWD GTCK,MWD ROP,MWD 47 3i"/ -999,250 483.155 -999.250 539,1i0 1.000 561.28! -999.250 491.796 TAB,MWD GR.MWD TAB.MWD GR,MWD TAB,MWD GR,MWD TAB MWD GR:MWD TAB,MWD GR.MWD TAB MWD GR.'MWD 0,~11 94, 25 0.!92 ill.065 95, 0,236 107,367 91, 40 **** FiLE TRAILER FILE NAME : EDIT ,00t SERVICE : FbIC VERSION i 00!A07 · DATE : 92/l!/25 MAX REC $IZ~ : I024 FILE TYPE : LO LAST FILE **** FIL~ HEADER FI~E NAME : EDIT ,002 SERVICE : FLIC VERSION : 00IA07 ATE : 92/1!/2~ AX RZ¢ SI~ : I024 F~bZ TYPE : LO LAST FIhE ~')LE HEADER RAW MWD Curves and log header data for each bit run in separate ~lies, IS Tape Verification Listing chlumberger Alaska Computing Center 25-NOV-1992 07~11 PAGES BIT RUN NUMBER: DEPTH INCREMENTI 0.1000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 3347.0 $ LOG HEADER DATA DATE bOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BlT.ROTATIONAL SPEED HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE~ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TO0~ TYPE CDR RESISTIVITY $ BOREHOLE. COND!TIONS MUD TYPE~ ! MUD DENSITY MUD VISCOSITY ~UD PHI ~UD CHLORIDES FLUID bOSS (C3)l ~AXI~U~ RECORDED TEMPERATURE (DEGF)I . RESISTIVITY (OHMM) AT TEMPERATURE' ( DEG ):F MUD AT MEASURED TEmPeRATURE :(MT)~ MUD A.T ~AX CIRCULATING TEMPERATURE~ MUD FILTRATE AT (MT): ~UD CAKE AT (MT): NEUTRON TOOL MATR~X~ MATR X DENSITY~ HOLE CORRECTION (IN): TOOL STANDOFF (IMf: ~WR FREQUENCY (HZ s STOP DEPTH 9800,0 29-0CT-92 FAST 2.3D V4.0 ~E~ORY 9800.0 9800.0 3347,0 9800,0 TOOL NUMBER RGS058 334!,0 !0,30 145,0 2,572 2' 372 SANDSTONE 2.65 6,500 73,0' IS Tape Verification Listing ChlUmberger AlasKa Computing Center 25-NOV-~{992 07:11 REMARKS~ THIS FILE CONTAINS THE GR AND RESISTIVITY SAMPbIN~ TICKS FOR RUNS LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VAbUE ~ 66 0 2 66 0 3 73 12 4 66 255 5 66 6 73 7 65 1! 66 85 12 6~ 13 66 0 14 65 FT 15 66 68 ~6 66 ~ 0 66 I , ** SET TYPE - CHAN ** . NAME 8ERV UNIT SERVICE APl AP1 API API FIbE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE C~ASS MOD NUMB SAMP EbEM CODE (HEX) p~ rT~I.~?? ooooo oo o ~ ~ ~ 4 ~8 o~ooooooo DATA ** DEPT,: 327'2.900 RTCK.O05 -999.250 GTCK,O05 i,O00 D~PT. 3399.900 RTCK.O05 1.000 ~TCK.O05 -999,250 DEPT' 3400.1o0 RTCK.O05 1.000 ~TCK.O05 -999,250 IS Tape Yerif!cation Listing cblumbergerAlaska Computing Center DEPTo DEPT, DEPT, DEPT, DFPT, D~PT, DEPT, DEPT. DEPT,. PEPT', DEPT,~ DEPT. DEpT. DEPT. DEPT. DEPT.= DEPT,~ DEPT. DEPT. DEPT'. DEPT. DEPT, DEpT.= OEPT. DEPT.= DEPT. 3599,900 RTCK.O05 3600,100 RTCK,O05 3799.900 RTCKoO05 3800,100 RTCK.O05 3999.900 RTCK.O05 4000.100 RTCK.O05 4199.900 RTCK.O05 4200.101 R?CK'O05 4399,900 RTCK,O05 4400.101 RTCK.O05 4599,900 RTCK,O05 4600,!01 RTCK,005 4799.900 RTCK..O05 4800.10~ RTCK,O05 4999,900 RTCK'O05 5000,!0! RTCK,O05 5199,900 RTCK,005 5200.i0~ RTCK,O05 5399,900 RTCK.O05 5400,10! RTCK,005 5599,900 RTCK,005 5600-10! RTCK,O05 5799'900 RTCK'O05 5800,!01 RTCK.,O05 5999.900 RTCK'O05 6000.I0% RTCK'O05 25-NOV-{992 07111 -999.250 GTCK.O05 -999,250 GTCK,O05 -999.250 GTCK,O05 -999.250 GTCK,O05 -999.250 GTCK,O05 -999,250 GTCK,O05 -999.250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,O05 -999,250 GTCK,005 -999,250 GTCK'O05 -999,250 GTCK,O05 -999,250 G?CK,O05 -999,250 GTCK,O05 -999,250 GTCK-O05 -999,250 GTCK,O05 1,000 GTCK*O05 1.000 GTCK,O05 '999,250 G?CK,O05 -999.250 GTCK,O05 -999,250 -999.250 -999.250 -999'250 -999.250 -999,250 1.000 !.000 '999.250 -999.250 .999.250 -999.250 -999,250 -999'250 '999,250 -999,250 -999,250 -999'250 -999'250 .999'290 .999'250 !.O00 -999,250 '999,250 '999,250 -999,250 PAGE! 10 IS Tape Verification blstlno chlumberger AlasRa Computing Center D~PT. DEPT. DEPT. D~PT. DEPT. D~PT. DEPT* DEPT. DEP?. DEPT. DEPT. DEPT, DEPT, DEPT, DEPT. DEPT, D~PT. DEPT*. DEPT, D~PT, DEPT, D£PT. DEPT, D~PT, OEPT, 6199.900 RTCK.O05 6200.101 RTCK.O05 6399.900 RTCK.O05 6400.101 RTCK.O05 6599.900 RTCK.005 6600.101 RTCK.O05 6799.900 RTCK.O05 6800.'101 RTCK.O05 6999.900 RTCK.O05 7000.101 RTCK.O05 7199.900 RTCK.O05 7200.&01 RTCK.005 7399.900 RTCK.O05 7400'!0! RTCK.O05 7599.900 RTCK.O05 7600.~01 RTCK-O05 7799.900 RTCK,iO05 7800.!01 RTCK.O05 7999"900 RTCK*005 8000,&01 RTCK,O05 8199.900 RTCK.O05 8~00.100 RTCK.O05 8399.900 RTCK'005 8400.100 RTCK.O05 8599.900 RTCK.O05 8600,100 RTCK.O05 25=NOV-Igg2 07111 -999.~50 GTCK,O05 '999.250 GTCK.O05 -999.250 GTCK.O05 1.000 GTCK.O05 -999.250 GTCK.O05 -999.250 GTCK.O05 1.O00 GTCK.O05 ~999.250 GTCK.005 -999.250 ~TCK.O05 -999.250 GTCK.O05 -999.250 GTCK.005 -999.250 GTCK.O05 -999.250 GTCK.O05 -999.250 GTCK.O05 -999.~50 GTCK.O05 -999.250 GTCK.O05 ~999.~50 GTCK.005 -999.250 ~TCK.O05 -999.250 GTCK,O05 1.000 GTCK,O05 -99g.250 GTCK.O05 -999.250 GTCK.O05 -999.250 GTCK.005 -999.~50 GTCK.005 -999.~50 GTCK.O05 ~999.250 GTCK..005 1.000 1.000 -99g,250 -999.250 =999.250 =ggg.250 -999.250 -999.250 -999.250 -999.250 -999.250 .99 . So. -999,250 -999.~50 =999.250 '999.250 1.O00 I.~000 -999.250 -999'250 '999'250 '999,2:50 -999,250 '999.250 11 IS Tape Yerlfication Listing chlumberger AlasKa Computing Center DEPT, 8799,900 RTCK,005 DEPT, 8800,I00 RTCK,005 DEPT, 8999,900 RTCK,005 D~PT, 9000,100 RTCK.005 DEPT, 9199,900 RTCK,005 DEPT, g200,100 RTCK,005 DEPT, 9399,900 RTCK,005 DEPT. 9400,100 RTCK,O05 DEPT, 9599,900 RTCK,005 DEPT, 9600,100 RTCK,005 DEPT, 9773,201 RTCK,005 END OF DATA 25-NOV=1992 07:!I, '999.250 GTCK.O05 '999,250 GTCK,O05 '999,250 GTCK,O05 '999,250 GTCK,O05 -999.250 GTCK,O05 -999.250 GTCK,O05 -999.250 GTCK.O05 -999,250 GTCK,O05 1.000 GTCK,O05 1.000 GTCK.O05 1.000 GTCK.O05 -999.250 -999.250 l,O00 1,000 -999.250 -999,250 1.000 l.O00 1.000 t.000 -999,250 12 FILE NAME . EDIT ,002 SERVICE ~ FLIC VERSION : 001A07 DATE : 92/11/25 MAX EBC:$1Z~ : !024 bAS? FIbE : FILE NAME . EDIT $~R:VICE : FLIC VERSION : 001A07 MAX REC SIZE : 10~ FILE TYPE : 50 LAST FILE FILE HE.ADE~ RAW MWD Curves and log header data for each bit run in separate files, DEPTH INCREmeNT: 0.5000 I$ Tape Verification Listing chlumbergerAlaska Computlno Center 25'NOV-1992 07:!1 PAGEI ¸13 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CDR 3347.0 $ ~OG HEADER DATA DATE LOGGED: SOFTWARE SURFACE $OFT~ARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT)~ TD LOGGER(FT): TOP LOG INTERVA~ BOTTOM LOG INTERVAL BIT ROTATIONAL SPEED ~OLE INCLINATION (DEC) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE CDR R~SISTIVITY $ ~DREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH BOREHOLE CONDITIONS ~UD STOP DEPTH 9239,0 MUD CHLORIDES FLUID LOSS CC~ MAXIMUM' RECORDED TEMP~RAT[,.RE (DE~F(~ F. RESISTIVITY (OHMS) AT TEMPERATURE DEG MUD AT MEASURED TEMPERATURE {~T~. MUD AT MAX CIRCULATIN~ TEMPERATURE:' MUD FILTRATE AT (MT): MUD CAKE AT NEUTRON TOOL MATRIX~ MATRIX DENSITY~ HOLE CORRECTION EW~ FREOUENCY 29-0CT-92 FAST 2,3D V4 0 2 33 ° TOOL NUMBER RGS058 8,500 3347'0 10,30 145,0 2,572 2,372 .500 73,0 73,0 IS Tape Verification Listing chlumberger Alaska Computing Center 25-NOV-1992 07:11 RGS READOUT PORT TO BIT: 68,9', GR TO BIT: 76 2' RESISTIVITY T6 B~T: 6556', DRILLED INTERVAL: 3347 - 9239' DRILLING DATA SAMPLED EVERY 20 ~ECONDS. DATA FROM DOWNHOLE ~EMORY. SOFTWARE V2,]D/4,0C 6IS FORMAT DATA PAGE: 14 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 4 66 5 66 8 68 0 5 I! 66 51 12 68 ~3 66 0 14 65 FT 15 66 68 0 66 1 ** SET TYPE - CHAN ** NAHE SERV UNIT SERVICE API APl AP1 API FILE NUHB NUNB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SA~P EbE~ CODE (HEX) ~.~ ~ ~.~ oo ooo oo o ~ ~ , ~ ~. oooooooooo A?~ ~w~ OH~M 61897~ O0 000 O0 0 ~ 1 ~ 4 6~ 0000000000 PS~ ~Wi OHMM ~}8977 O0 000 O0 0 ~ ~ I 4 68 0000000000 ROP~ 5WI F/HR u,8977 O0 000 O0 0 3 I 1 4 68 0000000000 ~ ~wi ~APZ 61~97~ oo ooo oo o ~ ~ I 4 ~8 oooooooooo 86L'81;t GO6'~6B 0~0'0~£ L6E'E~E OtL°£E~ 990'L9£ OLE'~ES O~L'96E LO[*L8C 1;mq'MdO~l tMq"3d08 99£'g SOY'i: 88E*t 8t6'£ ~Gg*t 9E~'£ ]Nq*Hgd 6Gt'Z lMq'~gd [O0't lMq*Hgd LGS'£ IMq'Hgd 60['E {Mq'3dOH 0Gg'666' IMq'Hgd 09g'666- I~q'~dOH 0Sg'666- tMq'agd 0~E'666- It:LO ~66~'AON-S~ 00S'08 lMq'aD 000'0009 :'IdaO ;Mq"a&Y' 000 00~9 ':&d30 ~Lg'8E~ I~q'aO B 8 [' 16 i M q ' a g IMq'a~V O00'O0~L ~d3. ]aq'~&~/ 000 'O.09L £43Q ;Mq'al{ O00'O08L &d3H O' 08~'90I IMq[aD IMq'~&V 000'0098 &d30 000'0088 000'0006 O~'666- ;Mq'~£V 009'8E~6 '&d3O Jalua3 bUl;3natao,D e>iselv JaB;~aqmnZqo bUI~Slq uol3eoI~;~aa aciej~ SI ~i)1~ "Lgs t1:~'88t ~99"~6~ LOO'E:I;9 6T8'S9~ [6L'L~9 I~'I'3dOa t~q'3dO~ t~q'3dO~{ INq'3dOH 9ig'~ ILO't E66'£ fL9'£ tNq"HSd L68'£ I~q*U~d O~9'E I~q*MSd IIlLO ~66]-AON=~ i~q'~£~ 000'00~[ '~dAO l~q'S&V 000'009~ ~d3O T~q*~&V 000'00 ~ : ~d3O 0I 660.96 Taq*~{ O0 OOg~ '~d3O ttT*tOT Taq*aD T~q*a~V O00'OOtt 'Zd3O LLT*88 Taq]aD Taq'H~V 000'008~ ~d3O ~g*TTT T~"I*~D TMq*H&Y O00*O00g *Zd3O 6Tt'86 TMq*HD TMq*~&~ 000'00~ '~d3O ; s']' aJ, v ooo' oo~,; &aaa L66'~6 iaq'uD Taq*~ O00*O09B '£d3O 8gO'E6 [~q'89 T~q*8gV 000'008~ *~d3O ~a~uaj bUT~ndmoj e~s~lV ~ab~aqmnTqo bUT~STq uoT~enT3TieA aae~ ~I 0.6~~6 0086 0'0086 0'0086 mmm~mmmmmm~mmmmmm $ mmmlmmmll mmmmmmmmmmlmmlmm 3d~£ ~OO& SGOD ~OO& ~OQN~A (~O&~Oa O~ dO&) DNIS~g qOO& :~qDN~ ~nWINI~ :O~DDOq .$ 0'6E[6 ~WWfl~ :a39NfiN Nfl8 LOVIO0 : NOIgB3A **** H30~3H 3qI& LOV~O0 : NOZ~83A 3Iq~ : ~3IAa3~ 99 0 99 0 99 m~m~i~mmm~mmm~m~mmmmmmm O'EL O'EL 90q ~0 ~N~g]'Bd iON BO~IOION1 9NI019~ 00~9 O'L)£E 00~'8 # · :(NI) NOI&33~OO 3qOH {3~fl~3dW~ DNI&~qfiD~iD X~W ~V OflW . :(ED) ggOQ OlflqJ ~(Wdd) g3Oz~oqH3 tHd OfiW :(S) A£IgOD~IA t3dA& SNOI£IQNOD :(&~) H£d3O 9NIgVD g83qqIBO :(NI) 3Zig ~IB 3qOH N3dO VZVQ 9NI~¥D GNV 3qOH3aOB it:LO ~66{'AON-S~ ~elueD bu)lndaoD e~seT¥ ~eb~aqmnlq~ bullsTq uoTleDT))~eA eue& S! 000'08~ ' · · ooo' 88L~L6 ZNq"~dOa 0~'666- [Nq'agd 0B.['666- [Mq'U~V 000 OOe6 000000 l oooooo°°°°o ~' ' ' ,o oo ooo .oo ~,~,,, ,~ ~.~ 000 89 ~ ] ] } 0 O0 000 O0 ~£68 9 8H/d 0000000000 89 ~ I T ~ 0 O0 000 O0 LL68~9 ~HO [~q 000000o000 ~9 ~ [ '~ ~ 0 oo 000 oo LL6a~9 ~aHO [~q 0000000000 89 ~ ~ ] ~ 0 O0 000 O0 LL68~9 &J m~mm~m~mmmmm~mmmmmmm~m~mmm I 99 0 I 99 89 99 0 99 t~ 99 Z3 ~9 6 ~'0 89 O ~g L EL g g9 ~mBamimm~al~W~mmmmmmmm~mm~al~m~mm~m~am~m~mm 6I Ie%uaD bu]3ndmoj e~se[¥ ~eb~aqmnlqo 0.6Eg6 0'6Eg6 O'~A S'89L6 $ 3dA~ qO0~ 3OOD qO0~ ~OGN3A :3qDN¥ WflWiN1W ~ q~A~3~I DOq ~0~ :NOigB3A 3~VM~O~ 3~IOXNMO~ :NOI~3A 3~VM&J09 3O~JMN~ :03DDOq S'00~6 HSd3Q $~ ~QOD qo0$ ~OON3A O00S'O :IN3~M~3NI g ~3~flN 35IJ : ~qI~ oq : 3dt$ 3qlJ D~Ot : 3ZI~ D~8 X~W LO~tO0 : NOI~3A Olq~ : 3OlA~Mg go0* ~I03 : 3W~N ~qi~ **** ~3OV3H 3qlJ : 3qI~ **** H3qIV~ 3ql~ **** O~ :3gVd ti:LO ~66t-AON-S~ buT~STq UOTleU'IlT~eA eae$ gl IS Tame Yerlflcatlon blstlnq chlumberger AlasKa Computin~ Center 07:11 PAGI~I. 21 BOREHObE AND CASING DATA OPEN HOLE BIT SIZE (IN), 8.500 DRILLERS CASING DEPTH (FT)I 33' 47 0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G]: 10,30 MUD VISCOSITY MUD PHI MUD CHLORIDES FLUID bOSS MAXIMUM RECORDED TEMPERATURE (DEGF)I 145.0 RESISTIVITY (OHMS) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT)I · 2,572 73 0 ~UD AT MAX CIRCULATING TEMPERATURE. ' MUD FILTRATE AT (MT): 2,372 73.0 MUD CAKE AT (MT): NEUTRON TOOL MATRIX~ SANDSTONE MATRI×..DENMITY: 2.65 HOLE CORRECTION CIN): ~.,500 TOOL STANDOFF (IN)~ EWR FREQUENCY (HZ): REMARK$I THIS FILE CONTAINS THE HIGH RESOLUTION RESISTIVITY DATA,. $ FOR~AT DATA DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64ES ** TYPE REPR CODE VALUE t 66 0 2 66 0 ,3 73 28 4 66 1 5 66 6 73 7 65 B 68 O 5 9 65 ! 66 36 12 68 !3 66 0 14 65 Tape Veri[icatlon Listing chlumbergerAlaska Computing Center 25-NOV-1992 07~11 ¸:22 TYPE REPR CODE VALUE 15 66 8 16 66 1 0 66 ** SET TYPE - CHAN ** ''''''''''''''''''''''''''' Ibg NUMB NUMB s~zE REPR PROCESS s .v X;i"X;i' ","'"""'"'"'"'"'"'"'"'"'""'"' ID ORDER # bOG TYPE CLA~S MOD NUMB SAMP ELEM CODE (HEX) m~~m~mmmmmm~mmmmm~mmmmmmmmmmmmmmmmmm~mmm~mmmmmmmmmmmmmmm~mm~m~m~mmm~m~m~mmm~mm DEPT FT 618977 O0 000 O0 0 5 1 1 4 68 ATPH 001 OHMM 61~977 O0 000 O0 0 5 I 1 4 68 PSPH 001 OHMM 618977 00 000 O0 0 5 I I 4 68 ATER OO1 OHMM 618977 00 000 00 0 5 1 I 4 68 PSE~ 00! OHM~ 618977 O0 000 O0 0 5 I I 4 68 ATVR 001 OHMM 618977 O0 000 O0 0 5 I I 4 68 PSV~ 001 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OHMM 618977 O0 000 O0 0 5 1 I 4 68 0000000000 ** DATA ** DEPT" 9769.500 ATPH.001 1.527 PSPH' ~ PSE,.001 3,587 ATVR.O01 .519 PSVR:i:~.11 DEPT'~ 9600'000 ATPH,OOI '3- ! PSPH.OOi PSER':O0! 3,582 ATVR;O01 31:27 , 533 PSVR,O01 PSER.Ooi 1'858 ATVR'O01 !'7!4 PSVR:~01 3-589 ATgR'OOi 3-581 3,370 ATER,OO1 3.636 ,878 ' END OF DATA 3.470 ,ov7 FILE NAME ~ EDIT ,005 SER¥ICE ~ FS!C VERSION : O0{,A07 DATE : 92/11/25 MAX REC SIZE { !024 FILE TYPE : bO 00~ 8 :oo6 0.0696' o ooaa 0.~696 0'0086 g6~AON-EO ~ ~'~ 6'^Oa'tO ~9~qOA IH ~O~VDOq ~VqqOD $ ~OqH &OqH &OqH ~dA~ qo0~ 3OOD qO0~ MOONMA 0'0088 H&d3O dO£g l(~J] QVAH3£NI 9Oq WO~&Oa I(&A) qVA~3&NI '90q :WO~O~ NO ~3990q :NOi~H3A O'OiL6 &QQH H&d~O ~9 3GOD qO0~ ~OQN3A el!~ lse! us ssea punozb~oeq aea Isel;"~ e~e~edas uI ssea q~ea ao~ e~ep Aepeaq bo! pue 9 ~WQN ~/)T/~6 : 3£VQ £0¥~00 : NOig~3A Jlq~ : 900~ ~IO3 : 3~N ;;:£0 ~66I'AON-S~ bUI~STq uo~eotTTae^ aae& ~I 80 99 0 99 13gVd # ******************************* 3NOg~ON~ 0'09; Og'OT 2NI~ # ~(gdD).3qVD~ HDiH 3~8 &NaOD l(~) MOONIM DNIZI~N~ON dO& I(NI) NOIgD3~80D 3qOH :XI~£VW # ICD~O) 3ROHD :OI£VB qIO/SVD :(WdB) O~3H~q3M ZV 3&VB oIAq3 :(~) q3A39 OlRqJ :(Ndd) X&iNIqVS Olaq~ :(~D3d) ~8fl£~3d~3Z ~qOH WO&~O~ I(JD3~) 3~{I~¥B3dW3Z 3D~J~fl~ 13d~ Olflq~ ti:LO ~66~-AON-~ OUT~STq UOT%eOT~T~eA aoe£ gI · L~L'£ 000'009.6 000 OIL6 3d m~mmmmm~mmmm~mmmmmmm##mmmmmmmmmmmmmmmm~m~mm 0000000000 89 ~ I I 9 0 O0 000 O0 £L68;9 IaV9 &O~H 0000000000 89 ~ I I 9 0 O0 000 O0 LL6et9 A &flq~ 0000000000 89 ~ I 'I 9 0 O0 000 O0 LL68t9 £D/D $~qH 0000000000 89 ~ I t 9 0 O0 000 O0 LL6819 £0/9 ~qH 0000000000 89 ~ t I 9 0 O0 000 O0 LL6819 £~/9 $flqH 0000000000 89 ~ I I 9 0 O0 000 O0 LL68~9 £D/~ £QqM 0000000000 89 ~ I t 9 0 O0 000 O0 LL6819 £~ m#~&m~mm~mmmm~mmmmmmammmmmmmmmmmmmmmmmmmmm~mmm~mm~mmmmmmmmmmmam~mm~m#mmm~mm~m~mm (X3H) ~QOD W3q3 d~ ~NflN QOW ggVQD 3dX& DOq # ~OSO i 99 0 I 99 89 99 0 g9 9i 99 i 99 ~liq~A 300~ ~d3~ 3dA& :3DVd tIILO ~66I-AON-S~ q ul3stq uot%e~l)laeA ade£ g! IS Tape Verification Listing chlumberger AlasKa Computing Center 25-NOV-1992 07:~t PAGICI 2~ END OF DATA **** FILE TRAILER **** FILE NANE : EDIT ,006 SERVICE ~ FLIC VERSION : O01A07 DATE : 92/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 92/11/25 ORIGIN : FLIC TAPE NAME : 92640 CONTINUATION # : PREVIOUS TAPE COMMENT : ARCO ALASKA, INC,,KUPARUK RIVER. UNIT,2M-01,50-103-,20185-OO **** REEL TRAI[,ER **** &ERVICE NAME : EDIT D.TEA : 92/11/25 ORIGIN : FbIC REEL NAME : 92640 C~NT!NUA. TION # : P..EVXOUS REEL : COMMENT ' ' : ARCO ALASKA, INC,.,KUPAR'UK RIVER UNIT,2M'OI,50-103-20!85-O0