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186-002
FALSE 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: 88 Total Depth:1487' FSL, 1388' FEL, Sec 23, T11N, R8E, UM 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: 23. BOTTOM 16"H-40 106' 9-5/8"J-55 2773' 7"L-80 2116' 7"J-55 5799' 5 L-80 6240' 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 8/22/2023 186-002/323-509 50-103-20056-01-00 KRU 2A-10 ADL 0025570 ALK 2688 1/30/1986 7260'MD/6248'TVD 6200'MD/5412'TVD 123' P.O. Box 100360 Anchorage, AK 99510-0360 498341 5960747 1208' FSL, 1218' FEL, Sec. 23, T11N, R8E, UM 2/6/19861326' FSL, 53' FEL, Sec 14, T11N, R8E, UM 5958214 1500'MD/1500'TVD SETTING DEPTH TVD 5957935 TOP HOLE SIZE AMOUNT PULLED 497176 497007 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. Kuparuk River Field/ Kuparuk River Oil Pool N/A BOTTOM CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, CASING WT. PER FT.GRADE CEMENTING RECORD 35' 18# 6690'35' 35' 6437' 2863' 6-1/8"140 sx Class G 62.5# 36# 106' 35'2126' 35' 200 sx ClassG, 175 sx CS 1 SIZE 24" DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): TUBING RECORD 6890'3.5" x 2-3/8" 5598' 12-1/4" 310 sx CS II 35' 810 sx AS III, 290 sx Class G 8-1/2" 35' 35' 8-1/2" 26# 7250' 6783-6837'MD, 6892-6902'MD, 6918-6950' MD (cemented) 5874-5918'TVD, 5961-5969'TVD, 5982-6007'TVD (cemented) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6288' Flow Tubing Sr Res EngSr Pet GeoSr Pet Eng None Oil-Bbl:Water-Bbl: 6184'MD/5399'TVD 6310'MD/5498'TVD 6867'MD/5941'TVD N/A Cement Plug: 6200-7000'MD 6390-7000'MD 29bbls 15.8ppg Class G thru retainer, 1 bbl on top of retainer Water-Bbl: PRODUCTION TEST N/A Date of Test:Oil-Bbl: 26# PACKER SET (MD/TVD) 3.5" J G s d 1b 10 D A 2 p and Bot ;Perfor L s (atta Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 0 By Grace Christianson at 9:53 am, Mar 28, 2024 Abandoned 8/22/2023 JSB RBDMS JSB 040924 xGDSR-4/23/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface Base of Permafrost 1500 1500 N/A N/A 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Adam klem Digital Signature with Date:Contact Email:adam.klem@cop.com Contact Phone:907-263-4529 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: 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 Top of Permafrost 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. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)FORMATION TESTS 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 INSTRUCTIONS Top of Productive Interval Authorized Title: Drilling Engineer Operations Summary, Cementing Summary, Well Schematic 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. N Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Adam Klem Digitally signed by Adam Klem Date: 2024.03.28 09:01:51 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,897.0 2A-10 12/2/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut @ 6138' RKB 2A-10 12/26/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: WORKOVER w/TOP 2122' PROD CSG REPLACED/TBG COMPLETION REPLACED 9/4/2010 lmosbor NOTE: ***SURFACE ANNULUS CEMENTED FROM 2122' TO SURFACE*** 8/16/2010 lmosbor 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 35.0 106.0 106.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 35.0 2,862.7 2,773.3 36.00 J-55 BTC PRODUCTION 7" Tie- Back w/Patch 7 6.28 24.8 2,125.6 2,115.7 26.00 L-80 TCII PRODUCTION 7 6.28 35.0 6,690.1 5,799.2 26.00 J-55 BTC LINER 5 4.28 6,437.0 7,250.0 6,240.0 18.00 L-80 LTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 6,140.0 Set Depth … 6,288.0 String Max No… 3 1/2 Set Depth … 5,480.8 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Mod 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) 6,154.7 5,376.3 38.24 SEAL ASSY 3.980 SEAL ASSEMBLY/LOCATOR SUB w/ 80-40 Seals w/ 8' space out Baker 80-40 3.020 6,163.3 5,383.0 38.22 PBR 4.950 20-ft. x 80-40 PBR Baker 20' x 80- 40 4.000 6,183.6 5,399.0 38.16 Packer 5.970 7" 47B2 FHL Packer Baker 47B2 - 7" 26# 2.910 6,232.5 5,437.4 38.32 NIPPLE 4.520 CAMCO 'DS' NIPPLE Camco "DS" 2.812 6,277.3 5,472.4 38.61 SEAL ASSY 3.980 SEAL ASSEMBLY w/no seals / Spaced out 1' off fully located Baker 80-40 3.020 Top (ftKB) 6,287.1 Set Depth … 6,889.3 String Max No… 2 3/8 Set Depth … 5,959.4 Tubing Description TUBING Original 3.5x2.375" Wt (lb/ft) 4.60 Grade N-80 Top Connection EUE BTC ID (in) 1.92 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) 6,296.6 5,487.6 38.73 PBR 5.125 BAKER PBR 3.000 6,310.4 5,498.3 38.72 PACKER 6.078 BAKER 'FHL' PACKER 3.000 6,350.9 5,529.9 38.58 PRODUCTION 5.390 CAMCO KBUG 2.920 6,390.3 5,560.7 38.45 NIPPLE 4.520 AVA BPL PORTED NIPPLE 2.310 6,393.2 5,563.0 38.44 XO 3.500 CROSSOVER 3.5"x2.875" 2.875 6,395.8 5,565.0 38.43 XO 2.875 CROSSOVER 2.875"x2.375" 2.375 6,786.8 5,877.3 35.92 BLAST JT 2.375 BLAST JOINTS (2) 1.920 6,859.5 5,935.8 37.35 LOCATOR 2.675 BAKER LOCATOR MODEL G-22 1.965 6,860.3 5,936.4 37.37 SEAL ASSY 2.675 BAKER SEAL ASSEMBLY w/MULE SHOE 1.965 6,866.6 5,941.5 37.53 PACKER 3.968 BAKER 'DB' 32-26 PACKER 2.688 6,869.6 5,943.8 37.60 SBE 3.568 BAKER 40-26 SEAL BORE EXTENSION 2.688 6,880.7 5,952.6 37.87 NIPPLE 2.687 CAMCO 'D' NIPPLE 1.813 6,888.6 5,958.8 38.07 SOS 2.875 CAMCO SHEAR OUT SUB/WLEG. TTL ELMD @ 6875' ON SWS PPROF 8/30/1999 2.441 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) 4,563.0 4,124.8 37.85 CASING LEAK CASING LEAK - ARCHER ACOUSTIC LDL 5-19-18 5/19/2018 6.276 6,118.0 5,347.4 38.33 WHIPSTOCK Baker whipstock top set @ 6,115.95'. Bottom of window @ 6133 BOWS set at 6138' ORKB. Adjusted RKB to 7es = Baker whipstock top set @ 6,122.95' - BTM of window @ 6,140' BOWS = 6,145' ORKB Baker G2 whipstoc k H1501 60001 2/18/2024 0.000 6,335.0 5,517.5 38.63 CEMENT RETAINER FH 1-TRIP CEMENT RETAINER 005- 2725- 500 8/22/2023 0.000 6,931.0 5,992.1 38.55 FISH Lower Seal & Ring From Blanking Sleeve; Lost in Well 2/6/1989 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) 6,350.9 5,529.9 38.58 6 PROD DMY BK-2 1 0.0 7/24/1990 Close d 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,149.7 6,162.1 39.05 LANDING COLLAR 5.000 4.276 2A-10, 3/27/2024 9:48:38 AM Vertical schematic (actual) LINER; 6,437.0-7,250.0 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 PACKER; 6,866.6 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 Cement Plug; 6,200.0 ftKB Packer; 6,183.6 WHIPSTOCK; 6,118.0 Liner; 32.6-7,130.8 CASING LEAK; 4,563.0 Mandrel – GAS LIFT; 4,371.1 SURFACE; 35.0-2,862.7 Mandrel – GAS LIFT; 2,688.5 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB CONDUCTOR; 35.0-106.0 Hanger; 24.5 KUP PROD KB-Grd (ft) 35.01 RR Date 2/8/1986 Other Elev… 2A-10 ... TD Act Btm (ftKB) 7,260.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005600 Wellbore Status PROD Max Angle & MD Incl (°) 39.55 MD (ftKB) 5,800.00 WELLNAME WELLBORE2A-10A Annotation Last WO: End Date 3/1/2024 H2S (ppm) 150 Date 11/20/2015 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,783.0 6,837.0 5,874.3 5,917.9 C-4, 2A-10 4/1/1986 12.0 IPERF 60 deg. ph; 3 3/8" HJ - II 6,892.0 6,902.0 5,961.5 5,969.4 A-4, 2A-10 4/1/1986 4.0 IPERF Gearhart 6,918.0 6,950.0 5,981.9 6,006.9 A-3, 2A-10 4/1/1986 6.0 IPERF 60 deg. ph; 3 3/8" HJ II Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,892.0 6,950.0 1 FRAC 10/15/1990 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,390.0 7,000.0 5,560.5 6,045.9 Cement Plug 8/22/2023 6,200.0 7,000.0 5,411.9 6,045.9 Cement Plug 8/22/2023 2A-10, 3/27/2024 9:48:39 AM Vertical schematic (actual) LINER; 6,437.0-7,250.0 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 PACKER; 6,866.6 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 Cement Plug; 6,200.0 ftKB Packer; 6,183.6 WHIPSTOCK; 6,118.0 Liner; 32.6-7,130.8 CASING LEAK; 4,563.0 Mandrel – GAS LIFT; 4,371.1 SURFACE; 35.0-2,862.7 Mandrel – GAS LIFT; 2,688.5 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB CONDUCTOR; 35.0-106.0 Hanger; 24.5 KUP PROD 2A-10 ... WELLNAME WELLBORE2A-10A Page 1/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/10/2024 12:00 2/10/2024 18:00 6.00 MIRU, MOVE MOB P Trucks on location moving Electrician shack, Tool shack ect...Set rig tongs on floor and Bridle up blocks. Set top drive in stump and BD steam and water lines. 0.0 0.0 2/10/2024 18:00 2/11/2024 00:00 6.00 MIRU, MOVE RURD P RDMO Perform rig down checklists, prep location for move, prep loads for transport to 2A pad 0.0 0.0 2/11/2024 00:00 2/11/2024 06:00 6.00 MIRU, MOVE MOB P Move Sub towards 2A-pad 0.0 0.0 2/11/2024 06:00 2/11/2024 12:00 6.00 MIRU, MOVE RURD P Rig on pad. prep for backing over 2A- 10. Spot over well back in pits, shim up rig and pits raise derrick continue working pre acceptance checklist. spot in kill tanks and cutting tanks. 0.0 0.0 2/11/2024 12:00 2/11/2024 14:30 2.50 MIRU, MOVE RURD P Move CDR3 service module from 2B- pad to 2A-pad. work post rig move checklist, Bring fluid into pits 0.0 0.0 2/11/2024 14:30 2/11/2024 20:30 6.00 MIRU, WELCTL RURD P Accept Rig @ 14:30pm. RU to kill well. Call pad operator to openSSSV. Inial PSI OA = cemented/ IA = 200 psi/ TBG = 350 psi 0.0 0.0 2/11/2024 20:30 2/11/2024 22:00 1.50 MIRU, WELCTL SEQP P PT surface lines to tiger tank 2500 psi. 0.0 0.0 2/11/2024 22:00 2/11/2024 23:00 1.00 MIRU, WELCTL DISP P Displace well with 285 bbls at 5 BPM/800 psi until clean seawater T/surface. 0.0 0.0 2/11/2024 23:00 2/11/2024 23:30 0.50 MIRU, WELCTL OWFF P Flow checked well- no flow. 0.0 0.0 2/11/2024 23:30 2/12/2024 00:00 0.50 MIRU, WELCTL MPSP P Set BPV. 0.0 0.0 2/12/2024 00:00 2/12/2024 02:00 2.00 MIRU, WHDBOP NUND P ND tree, function LDS, clean and inspect hanger threads, 10 turns with XO. Install blanking plug. 0.0 0.0 2/12/2024 02:00 2/12/2024 05:00 3.00 MIRU, WHDBOP NUND P Install DSA and set stack on wellhead. TQ flanges and install riser. 0.0 0.0 2/12/2024 05:00 2/12/2024 08:00 3.00 MIRU, WHDBOP OTHR P MU XO's and TIW's T/test joints, Mark donut joint for rams. Steam IBOP, BD top drive, MU sub to top drive. RU test hoses. Fill stack, choke manifold and purge all air from choke and 5.5 test joint. 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 2/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/12/2024 08:00 2/12/2024 18:00 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3,500 PSI for 5 Min each W/ 3 1/2" and 5 1/2" test joints. Test #1: Blind Rams, CMV 1,2,3, & 16, 2" Rig Floor Kill, IBOP, Outer Test SPool Valve. Test #2: Blind Rams, CMV, 4,5,& 6, HCR Kill, Inner Test Spool Valve, Manual IBOP, PU 5 1/2" TJ. Test #3: LPR, XT- 39 TIW, XT-39 dart valve. Test #4: UPR, CMV 7-8-9, Manual kill. Test #5: Super and manual adjustable choke (1,500 psi). Test #6: Annular, CMV 10- 11, Manual Kill. PU 3 1/2" TJ. Test #7: LPR, 3 1/2" FOSV. Test #8: UPR, CMV 12-13-15. Test #9: Annular, CMV 14. Test #10: HCR Choke. Test #11: Manual Choke. Perform accumulator test. Initial pressure = 3,000 PSI, after closure = 1550 PSI, 200 PSI attained = 14 sec, full recovery attained = 114 sec. UVBR's = 5 sec, Annular= 28 sec. Simulated blinds = 5 sec. LVBR’s = 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average = 2050 PSI. Test gas detectors, PVT, and flow show. Test Witness by AOGCC rep Brian D Bixby. 0.0 0.0 2/12/2024 18:00 2/12/2024 19:00 1.00 MIRU, WHDBOP RURD P Blowdown lines. Drain Stack. R/D testing equipment. Clean and clear rig floor. Prep floor to pull 3 1/2" Completions. 0.0 0.0 2/12/2024 19:00 2/12/2024 20:00 1.00 MIRU, WHDBOP MPSP P Pull slip-on blanking plug. Pull BPV. 0.0 6,138.0 2/12/2024 20:00 2/12/2024 21:30 1.50 SLOT, RPCOMP THGR P M/U and screw in landing joint to hanger neck threads. Set 10K down with Top Drive. BOLDS. PJSM. Unseated hanger @ 90K. Pull tubing hanger to rig floor @ 80K. 6,138.0 6,111.0 2/12/2024 21:30 2/12/2024 22:00 0.50 SLOT, RPCOMP RURD P L/D tubing hanger and pup. L/D landing joint. OWFF for 15-min. M/U head pin and circ. hose. 6,111.0 6,111.0 2/12/2024 22:00 2/12/2024 22:30 0.50 SLOT, RPCOMP CIRC P Circ BU. Pump 170 bbls 8.6# Seawater @ 5 BPM and 380 psi. Maintaining 1:1 returns. Measured 8.6# in and out. 6,111.0 6,111.0 2/12/2024 22:30 2/12/2024 22:45 0.25 SLOT, RPCOMP OWFF P OWFF. 6,111.0 6,111.0 2/12/2024 22:45 2/13/2024 00:00 1.25 SLOT, RPCOMP PULL P Pull 3 1/2" completions from 6,111' to midnight depth of 5,370'. 6,111.0 5,370.0 2/13/2024 00:00 2/13/2024 06:30 6.50 SLOT, RPCOMP PULL P Continue pulling 3 1/2" completions from 5,370' to surface. L/D21.22' cut joint. 5,370.0 0.0 2/13/2024 06:30 2/13/2024 11:30 5.00 SLOT, RPCOMP RURD P Clean and clear rig floor. Load the rest of the drill pipe. Install wear ring. Continue to lioad drill pipe, heavy weight and collars in shed to strap and tally. Load tools for drift/cleanout run. 0.0 0.0 2/13/2024 11:30 2/13/2024 12:00 0.50 SLOT, RPCOMP SVRG P Service rig 0.0 0.0 2/13/2024 12:00 2/13/2024 14:00 2.00 SLOT, WHPST BHAH P PU BHA #1 drift/cleanout (Window mill, Lower mill, flex joint, upper mill, bit sub, HWDP, MWD, 2 jts HWDP, drilling jars, 4 jts HWDP and 3 string magnets) 0.0 360.0 2/13/2024 14:00 2/13/2024 22:00 8.00 SLOT, WHPST PULD P RIH with BHA #1 F/360' T/6,130' RIH F/pipe shed 125K UP 108K DN 360.0 6,130.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 3/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/13/2024 22:00 2/13/2024 22:30 0.50 SLOT, WHPST PULD P Slack off F/6,130' T/6,145', tag @ 13K DN @ 6145.82' P/U 10', bring on pump @ 4 BPM 590 PSI, slack off tag @ 6146.29' W/25K DN x 3 6,130.0 6,146.0 2/13/2024 22:30 2/14/2024 00:00 1.50 SLOT, WHPST CIRC P Pump 33 BBL Hi vis sweep S/S Chase with 8.6 PPG seawater @ 6 BPM 1100 PSI Stand one stand back T/6,060' 6,146.0 6,060.0 2/14/2024 00:00 2/14/2024 00:30 0.50 SLOT, WHPST OWFF P B/D top drive, flow check 6,060.0 6,060.0 2/14/2024 00:30 2/14/2024 02:45 2.25 SLOT, WHPST TRIP P POOH F/6,060' T/360' 6,060.0 360.0 2/14/2024 02:45 2/14/2024 04:30 1.75 SLOT, WHPST BHAH P L/D BHA #1 Nothing on magnets 360.0 0.0 2/14/2024 04:30 2/14/2024 05:00 0.50 SLOT, WHPST BHAH P Clean clear rig floor 0.0 0.0 2/14/2024 05:00 2/14/2024 05:30 0.50 SLOT, WHPST BHAH P M/U BHA #2 TST-3 test packer 0.0 17.0 2/14/2024 05:30 2/14/2024 07:30 2.00 SLOT, WHPST PULD P RIH F/15' T/4457' Pick up singles from pipe shed 17.0 1,444.0 2/14/2024 07:30 2/14/2024 09:00 1.50 SLOT, WHPST TRIP P RIH F/1440 T/4457' From derrick 95K UP 87K DN 1,444.0 4,457.0 2/14/2024 09:00 2/14/2024 11:00 2.00 SLOT, WHPST PRTS P Set Test packer @ 4,452' C.O.E.,attempt to test 7" CSG above T/2000 PSI, pump 0.5 bpm and could only get up to 619 psi. Failed Test Move test packer up hole 1 stand to 4393' 4,388' C.O.E.. Set Test packer, pump 0.5 bpm with same results. 4,457.0 4,393.0 2/14/2024 11:00 2/14/2024 11:30 0.50 SLOT, WHPST PRTS P Trip out of hole 10 stands. Set Test packer at 3411' 3,406' C.O.E., Pump 0.5 bpm pressured up to 2005 psi in 18 strokes and held solid for 15 minutes. Good Test 4,393.0 3,411.0 2/14/2024 11:30 2/14/2024 14:00 2.50 SLOT, WHPST PRTS P Trip in hole 5 stands. Set Test packer at 3886'. 3,881' C.O.E. 80K UP 77K DN Test back side Pump 0.5 bpm pressured up to 2173 psi in 20 strokes and held solid for 15 minutes. Good Test 3,411.0 3,886.0 2/14/2024 14:00 2/14/2024 14:30 0.50 SLOT, WHPST PRTS P Trip in hole 3 stands. Set Test packer at 4171' 4,166' C.O.E., 3,886.0 4,171.0 2/14/2024 14:30 2/14/2024 17:30 3.00 SLOT, WHPST PRTS P Test packer at 4,171', 4,166' C.O.E., Pump 1.5 bpm pressured up to 2192 psi in 21 strokes and held solid for 15 minutes. Good Test. Perform 20 minute LOT: pump 0.5 bpm at 35 strokes pressure broke over at 600 psi and stayed flat. Shut In for 20 minutes and pressure held pretty solid only losing 34 psi in 20 minutes. Perform 20 minute LOT: pump 3.0 bpm at 22 strokes pressure hit 750 psi so we SIt. Shut In for 20 minutes and pressure held pretty solid only losing 99 psi in 20 minutes. 4,171.0 4,171.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 4/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/14/2024 17:30 2/14/2024 18:00 0.50 SLOT, WHPST PRTS P RIH F/4,171' T/4,330' Set packer @ 4,325 C.O.E. Attempt to test 7" casing, get to 630 PSI and break over, bad test 90K UP 83K DN 4,171.0 4,330.0 2/14/2024 18:00 2/14/2024 19:00 1.00 SLOT, WHPST PRTS P Pick up to 4,292', 4,287' C.O.E. Test 7" casing to 2000 PSI F/15 Min, OA = 0 PSI Good test Hole in 7" casing between 4,325' and 4,287' Bleed off PSI, open rams, slack off T/4,393', B/D all lines and top drive 90K UP 83K DN 4,330.0 4,393.0 2/14/2024 19:00 2/14/2024 21:00 2.00 SLOT, WHPST TRIP P RIH F/4,393' T/6,133' 105K UP 90K DN Blend mud at CDR pits to 10.5 PPG and haul to rig 4,393.0 6,133.0 2/14/2024 21:00 2/15/2024 00:00 3.00 SLOT, WHPST SLPC P Slip/cut 70' drilling line Grease crown, top drive, service rig Blend mud at CDR pits to 10.5 PPG and haul to rig 6,133.0 6,133.0 2/15/2024 00:00 2/15/2024 01:30 1.50 SLOT, WHPST COND P Blend mud at CDR pits to 10.5 PPG, build 8.6 PPG Hi vis spacer Prep pits for displacement Flush mud pumps with 10.5 PPG LSND 6,133.0 6,133.0 2/15/2024 01:30 2/15/2024 03:00 1.50 SLOT, WHPST DISP P Pump 33 BBLS 8.6 PPG Hi Vis spacer Chase with 280 BBLS 10.5 PPG LSND mud Pump @ 4 BPM 430 PSI Lots of sand back when 10.5 PPG mud back to surface 6,133.0 6,133.0 2/15/2024 03:00 2/15/2024 04:30 1.50 SLOT, WHPST CIRC P Circulate condition mud @ 3.9 BPM 444 PSI Start staging pumps up in 1/4 BBL increments to establish a loss rate 3.9 BPM/165 GPM 444 PSI 4.1 BPM/175 GPM 470 PSI 4.4 BPM/185 GPM 500 PSI 4.6 BPM/195 GPM 545 PSI 4.8 BPM/205 GPM 570 PSI 5.1 BPM/215 GPM 590 PSI 5.3 BPM/225 GPM 620 PSI Note: lots of sand come back until 6700 STKS after mud to surface 386 BBLS = 2.7 bottoms up Circulate a total of 447 BBLS after 10.5 PPG mud back 6,133.0 6,133.0 2/15/2024 04:30 2/15/2024 05:00 0.50 SLOT, WHPST OWFF P Flow check, B/D top drive 6,133.0 6,133.0 2/15/2024 05:00 2/15/2024 08:30 3.50 SLOT, WHPST TRIP P POOH F/6,133' T/17' UWT=120K DWT=95K 6,133.0 17.0 2/15/2024 08:30 2/15/2024 09:00 0.50 SLOT, WHPST BHAH P L/D TST-3 test packer Clean and clear rig floor 17.0 0.0 2/15/2024 09:00 2/15/2024 09:30 0.50 SLOT, WHPST RURD P Pull wear bushing 0.0 0.0 2/15/2024 09:30 2/15/2024 10:00 0.50 SLOT, WHPST NUND P Prep to ND BOP, BD choke and kill lines, pull riser, release chains from BOP 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 5/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/15/2024 10:00 2/15/2024 14:00 4.00 SLOT, WHDBOP WAIT T Waiting on a 7" CSG spear W/pack off from Baker in Dead Horse. At 14:00 HRS 7" spear on location Process 5 1/2" HYD 563 pipe 0.0 0.0 2/15/2024 14:00 2/15/2024 15:30 1.50 SLOT, WHDBOP NUND T Start to nipple down BOP, realize spear has wrong size pack off installed, call for correct pack off from Baker shop. Break spear apart, fill hole W/2 BBLS mud 0.0 0.0 2/15/2024 15:30 2/15/2024 17:00 1.50 SLOT, WHDBOP WAIT T Waiting on correct packoff from Baker in Dead Horse. Continue to process 5 1/2" HYD 563 and HYD 521 pipe in shed 0.0 0.0 2/15/2024 17:00 2/15/2024 17:30 0.50 SLOT, WHDBOP OWFF P With stack drained Flow check the well in accordance with the Corporate dispensation. No flow. Start operation inaccordance with Corporate Dispensation. 0.0 0.0 2/15/2024 17:30 2/15/2024 19:00 1.50 SLOT, WHDBOP NUND P Loosen choke/kill lines on stack, N/D BOP and rack back on stump 0.0 0.0 2/15/2024 19:00 2/15/2024 19:15 0.25 SLOT, WHDBOP RURD P Remove 13 5/8" 5K x 7 1/16" 5K DSA, check hanger void 0.0 0.0 2/15/2024 19:15 2/15/2024 20:30 1.25 SLOT, WHDBOP NUND P N/D TBG head adaptor and remove 2 1/16" gate valve from side outlet 0.0 0.0 2/15/2024 20:30 2/15/2024 22:45 2.25 SLOT, WHDBOP NUND P N/U FMC 5 1/2" casing head, install 2 1/16" side out let valve on IA 0.0 0.0 2/15/2024 22:45 2/15/2024 23:15 0.50 SLOT, WHDBOP PRTS P Test pack off and 11" 3K flange T/3000 PSI F/10 min 0.0 0.0 2/15/2024 23:15 2/16/2024 00:00 0.75 SLOT, WHDBOP NUND P N/U 13 5/8" x 11" 5K DSA, set test plug, get RKB to 5 1/2" CSG head lock downs 26.77' 0.0 0.0 2/16/2024 00:00 2/16/2024 01:00 1.00 SLOT, WHDBOP NUND P P/U stack off BOP stump and N/U BOP stack on wellhead 0.0 0.0 2/16/2024 01:00 2/16/2024 04:15 3.25 SLOT, WHDBOP NUND P Tighten nuts on BOP stack, DSA Install riser and tighten choke and kill line flanges up Hook up turn buckles and center stack 0.0 0.0 2/16/2024 04:15 2/16/2024 05:00 0.75 SLOT, WHDBOP RURD P Fill stack with water, purge air from lines, rig up to test BOP breaks 0.0 0.0 2/16/2024 05:00 2/16/2024 05:30 0.50 SLOT, WHDBOP BOPE P Test BOP breaks to 250/3500 PSI 5 min each. Off Cororation Dispensation. 0.0 0.0 2/16/2024 05:30 2/16/2024 07:00 1.50 SLOT, WHDBOP RURD P Rig down testing equipment, blow down lines Pull test plug, set wear ring, LD spear, pull test plug, set wear ring, run in LDS and LD running tool and single joint of drill pipe. 0.0 0.0 2/16/2024 07:00 2/16/2024 10:00 3.00 SLOT, WHDBOP BHAH P MU Whipstock BHA #2. T/353' Whipstock has 35K shear bolt and anchor has 10,695 LB shear pins 0.0 353.0 2/16/2024 10:00 2/16/2024 11:30 1.50 SLOT, WHDBOP TRIP P RIH F/353' T/1,389' Max running speed 60 FPM 54K UP 54K DN 353.0 1,389.0 2/16/2024 11:30 2/16/2024 12:00 0.50 SLOT, WHDBOP DHEQ P Shallow test MWD tool at 138 GPM 350 PSI Blow down top drive 1,389.0 1,389.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 6/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/16/2024 12:00 2/16/2024 16:00 4.00 SLOT, WHPST TRIP P RIH F/1,389' T/6058' 120K UP 100K DN 1,389.0 6,058.0 2/16/2024 16:00 2/16/2024 17:00 1.00 SLOT, WHPST WPST P Orient the WS to 45 LOHS Set down 12K at 6143' to set WS and saw a good shear, top of whipstock @ 6,123' PU 122K (only 2K above UPW) and no whipstock Rotate 8 RPM, TQ limit set at @ 3K to stall out rotatry, lug back up mills to whipstock, tool face go to 116° ROHS - 180° out from planned, P/U see 30K over pull then pick up clean Confirm tool face again at 123° ROHS with mills lugged up to whipstock We believe the WS was disconnected from the BHA and we just pushed it to bottom. 6,058.0 6,143.0 2/16/2024 17:00 2/16/2024 21:15 4.25 SLOT, WHPST CIRC P Circulate, stage up pumps 350 GPM or 12.1 ECD max to montior loss rate 223 GPM 940 PSI 11.3 ECD - no losses 250 GPM 1220 PSI 11.6 ECD down to 11.5 ECD - no losses 260 GPM 1300 PSI 11.6 ECD down to 11.5 ECD - no losses 270 GPM 1330 PSI 11.5 ECD - pump 38 BBL 11.7 PPG 85 Vis, weighted high vis sweep, max ECD = 12.0 when sweep coming up hole - no losses 280 GPM 1450 PSI 11.7 ECD down to 11.6 ECD - no losses 290 GPM 1540 PSI 11.8 ECD - down to 11.7 ECD - no losses 300 GPM 1620 PSI 11.8 ECD - no losses 310 GPM 1720 PSI 12-11.8 ECD - no losses 320 GPM 1800 PSI 11.9-12.0 ECD - no losses 330 GPM 1900 PSI 12.0 - 12.1 ECD - no losses 340 GPM 1990 PSI 11.9 - 12.1 ECD - no losses 350 GPM 2100 PSI 12.0 - 12.1 ECD - no losses 2 1/2 bottoms up before well cleaned up. Mud samples sent to D142 Geologist for analisis. 6,143.0 6,143.0 2/16/2024 21:15 2/16/2024 22:00 0.75 SLOT, WHPST OWFF T Flow check- slight flow, static in 15 min 6,143.0 6,143.0 2/16/2024 22:00 2/16/2024 22:30 0.50 SLOT, WHPST OTHR T Pump 15 BBL 12.5 PPG dry job B/D top drive 6,143.0 6,143.0 2/16/2024 22:30 2/17/2024 00:00 1.50 SLOT, WHPST TRIP T POOH F/6,143' T/3,200' 120K UP 100K DN 6,143.0 3,200.0 2/17/2024 00:00 2/17/2024 01:30 1.50 SLOT, WHPST TRIP T POOH F/3,200' T/331' 3,200.0 331.0 2/17/2024 01:30 2/17/2024 01:45 0.25 SLOT, WHPST OWFF T Flow check - static 331.0 331.0 2/17/2024 01:45 2/17/2024 03:30 1.75 SLOT, WHPST BHAH T L/D BHA #4 331.0 0.0 2/17/2024 03:30 2/17/2024 04:15 0.75 SLOT, WHPST BHAH T Clean clear rig floor 0.0 0.0 2/17/2024 04:15 2/17/2024 05:30 1.25 SLOT, WHPST BHAH T M/U BHA #5 T/80' whipstock hook MWD off set @ 216° 0.0 80.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 13/16 2A-10 Report Printed: 3/21/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/25/2024 08:00 2/25/2024 13:00 5.00 COMPZN, CEMENT OWFF T OWFF 5.5" x 7" casing flowing inconsistent return rates. Continue to process 3.5" tubing 22 gallons returned in 5 Hrs @ 4.4 GPH average 13:00 Hrs. light crude in returns. Called out E-Line to perform CBL. 7,130.0 7,130.0 2/25/2024 13:00 2/25/2024 15:00 2.00 COMPZN, CEMENT OWFF T RU secondary kill IA. Install 4.5" FOSV and Otis connection on casing stump. Continue to monitor IA returns and log flow back rates and volumes. Continue to process tubing. E-line on location at 1500. 7,130.0 7,130.0 2/25/2024 15:00 2/25/2024 20:00 5.00 COMPZN, CEMENT OWFF T Continue to OWFF, 28 Gallons returned total for additional 6 Bbls in 5 Hrs. flow diminishing T/ 1.6 GPH. Trace crude in returns. Spot in logging unit. Mobilize PC equipment T/ RF. Re head E-line. 7,130.0 7,130.0 2/25/2024 20:00 2/26/2024 00:00 4.00 COMPZN, EVALWB ELNE T PJSM with HES E-Line and Nabors. RU E-Line to hoist Bond log. Continue to OWFF, 30 Gallons returned total for additional 2 Bbls in 4 Hrs, flow diminishing T/ ..5 BPH average. 7,130.0 7,130.0 2/26/2024 00:00 2/26/2024 01:30 1.50 COMPZN, EVALWB ELNE T Complete R/U HES lubricator w/ full PC. M/U CBL tool string. 0 @ RF. Stab on. Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 01:30 2/26/2024 02:00 0.50 COMPZN, EVALWB PRTS T PT lubricator T/ 3500 PSI; Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 02:00 2/26/2024 04:00 2.00 COMPZN, EVALWB ELNE T Attempt T/ RIH. Unable T/ move down hole. Believe grease head to be problem. R/U steam hose & steam grease head. Unsuccessful in achieving line movement. Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 04:00 2/26/2024 04:30 0.50 COMPZN, EVALWB SFTY T PJSM w/ HES & rig crew on R/D lubricator to get to grease head. Continue to monitor IA. 7,130.0 7,130.0 2/26/2024 04:30 2/26/2024 07:00 2.50 COMPZN, EVALWB ELNE T R/D lubricator & PC. L/D tool string. Send lubricator down skate to troubleshoot grease head. Continue to OWFF, 32,63 Gallons returned total for additional 2.63 Gal in 6 Hr. Flow @ .438 GPH average. 7,130.0 7,130.0 2/26/2024 07:00 2/26/2024 11:30 4.50 COMPZN, EVALWB WAIT T Wait on HES personnel to get some sleep. Close LPR, shut IA in let pressure build for 1 Hr.0 PSI. Bleed off IA .5 gal returned. Continue with same schedule. 7,130.0 7,130.0 2/26/2024 11:30 2/26/2024 12:00 0.50 COMPZN, EVALWB SVRG T Service rig. Grease roughneck @ pipe skate. 7,130.0 7,130.0 2/26/2024 12:00 2/26/2024 14:00 2.00 COMPZN, EVALWB WAIT T Wait on HES personnel to get some sleep. Shut IA in let pressure build for 1 Hr.0 PSI. Bleed off IA .4 gal returned. Continue with same IA schedule. 7,130.0 7,130.0 2/26/2024 14:00 2/26/2024 17:00 3.00 COMPZN, EVALWB ELNE P R/U E-line lubricator & tool string w/ full PC. Stab on. Continue with same IA schedule; 7,130.0 7,130.0 2/26/2024 17:00 2/26/2024 17:30 0.50 COMPZN, EVALWB PRTS P PT lubricator T/ 500 PSI for 5 Min. Continue with same IA schedule 7,130.0 7,130.0 Rig: NABORS 7ES RIG RELEASE DATE 3/1/2024 Page 1/1 2A-10 Report Printed: 3/27/2024 Cement Cement Details Description Cement Plug Cementing Start Date 8/22/2023 00:00 Cementing End Date Wellbore Name 2A-10 Comment Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 6,390.0 Bottom Depth (ftKB) 7,000.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Cement Plug Page 1/1 2A-10 Report Printed: 3/27/2024 Cement Cement Details Description Cement Plug Cementing Start Date 8/22/2023 00:00 Cementing End Date Wellbore Name 2A-10 Comment Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 6,200.0 Bottom Depth (ftKB) 7,000.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Cement Plug STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________KUPARUK RIV UNIT 2A-10 JBR 04/05/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 3 1/2" and 5 1/2" test joints. Tested all Gas Alarms and PVT's. HCR Choke and 2 1/16" valves were serviced and passed retest. Precharge Bottles = 11@1100psi. Test Results TEST DATA Rig Rep:K. Cobzy / P. YearoutOperator:ConocoPhillips Alaska, Inc.Operator Rep:R. Philipps Rig Owner/Rig No.:Nabors 7ES PTD#:1860020 DATE:2/12/2024 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopBDB240214075307 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 10 MASP: 1733 Sundry No: 323-509 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 3 1/2"x5 1/2"P #2 Rams 1 Blinds P #3 Rams 1 3 1/2"x5 1/2"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"FP Kill Line Valves 2 3 1/8", 2"P Check Valve 0 NA BOP Misc 1 2 1/16"FP System Pressure P3000 Pressure After Closure P1550 200 PSI Attained P14 Full Pressure Attained P114 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P5@2050 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P28 #1 Rams P5 #2 Rams P5 #3 Rams P5 #4 Rams NA #5 Rams NA #6 Rams NA HCR Choke P1 HCR Kill P1 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 106' 9-5/8" J-55 2773' 7" J-55 5799' 5" L-80 6240' 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 Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: IA: 6390-7000' Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 29 bbls 15.8 ppg Class G Cement thru retainer, 1 bbl on top of retainer Flow Tubing Tubing: 6200-7000' Plugged for Redrill 6783-6837', 6892-6902', 6918-6950' MD (Cemented) 5874-5918', 5961-5969', 5982-6007' TVD (Cemented) Gas-Oil Ratio:Choke Size: 6867' MD/ 5941' TVD Per 20 AAC 25.283 (i)(2) attach electronic information 26# 7250' 35' 5598' 62.5# 36# 106' 35' 6690' SIZE DEPTH SET (MD) 6184' MD/ 5399' TVD PACKER SET (MD/TVD) 24" CASING WT. PER FT.GRADE 2/6/1986 CEMENTING RECORD 5958214 1500' MD/ 1500' TVD SETTING DEPTH TVD 5957935 TOP HOLE SIZE AMOUNT PULLED 497176 497007 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 9. Ref Elevations: KB: 123' 50-103-20056-00-00 KRU 2A-10 ADL0025570 1326' FSL, 53' FEL, Sec. 14, T11N, R8E, UM 1487' FNL, 1388' FEL, Sec. 23, T11N, R8E, UM ALK 2688 1/30/1986 7260' MD/ 6248' TVD 6200' MD/ 5412' TVD P.O. Box 100360, Anchorage, AK 99510-0360 498341 5960747 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/15/2023 186-002/ 323-329 BOTTOM 12-1/4" 310 sx CS II 35'810 sx AS III, 290 sx Class G 18# 35' 6437' 2863'35' 35' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 140 sx Class G6-1/8" TUBING RECORD 200 sx Class G, 175 sx CS I8-1/2" 6310' MD/ 5498' TVD 6890'3-1/2" x 2-3/8" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 8:46 am, Nov 28, 2023 Suspended 10/15/2023 JSB RBDMS JSB 112923 G DSR-1/26/24 x Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1500' 1500' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: N/A - Plugged for Redrill N/A - Plugged for Redrill 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. 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 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 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: 2023.11.27 10:07:11-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,897.0 2A-10 12/2/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cement Job 2A-10 8/22/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE: WORKOVER w/TOP 2122' PROD CSG REPLACED/TBG COMPLETION REPLACED 9/4/2010 lmosbor NOTE: ***SURFACE ANNULUS CEMENTED FROM 2122' TO SURFACE*** 8/16/2010 lmosbor 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 35.0 106.0 106.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 35.0 2,862.7 2,773.3 36.00 J-55 BTC PRODUCTION 7" Tie- Back w/Patch 7 6.28 24.8 2,125.6 2,115.7 26.00 L-80 TCII PRODUCTION 7 6.28 35.0 6,690.1 5,799.2 26.00 J-55 BTC LINER 5 4.28 6,437.0 7,250.0 6,240.0 18.00 L-80 LTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth … 6,288.0 Set Depth … 5,480.8 String Max No… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Mod 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) 33.0 33.0 0.00 HANGER 7.062 FMC 7 1/16" x 3 1/2" EUE TUBING HANGER w/ 3 1/2 Pup jt. FMC P#82- 747-236 2.900 513.9 513.8 1.41 NIPPLE 4.520 CAMCO 'DS' NIPPLE Camco "DS" 2.875 2,521.7 2,483.1 27.55 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 3,768.4 3,495.5 37.18 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 4,763.6 4,283.8 37.41 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 5,602.6 4,947.1 38.65 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 6,097.7 5,331.5 38.39 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 6,154.7 5,376.3 38.24 SEAL ASSY 3.980 SEAL ASSEMBLY/LOCATOR SUB w/ 80-40 Seals w/ 8' space out Baker 80-40 3.020 6,163.2 5,383.0 38.22 PBR 4.950 20-ft. x 80-40 PBR Baker 20' x 80- 40 4.000 6,183.6 5,399.0 38.16 Packer 5.970 7" 47B2 FHL Packer Baker 47B2 - 7" 26# 2.910 6,232.5 5,437.4 38.32 NIPPLE 4.520 CAMCO 'DS' NIPPLE Camco "DS" 2.812 6,277.2 5,472.4 38.61 SEAL ASSY 3.980 SEAL ASSEMBLY w/no seals / Spaced out 1' off fully located Baker 80-40 3.020 Top (ftKB) 6,287.1 Set Depth … 6,889.3 Set Depth … 5,959.4 String Max No… 2 3/8 Tubing Description TUBING Original 3.5x2.375" Wt (lb/ft) 4.60 Grade N-80 Top Connection EUE BTC ID (in) 1.92 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) 6,296.6 5,487.6 38.73 PBR 5.125 BAKER PBR 3.000 6,310.4 5,498.3 38.72 PACKER 6.078 BAKER 'FHL' PACKER 3.000 6,350.9 5,529.9 38.58 PRODUCTION 5.390 CAMCO KBUG 2.920 6,390.3 5,560.7 38.45 NIPPLE 4.520 AVA BPL PORTED NIPPLE 2.310 6,393.2 5,563.0 38.44 XO 3.500 CROSSOVER 3.5"x2.875" 2.875 6,395.8 5,565.0 38.43 XO 2.875 CROSSOVER 2.875"x2.375" 2.375 6,786.8 5,877.3 35.92 BLAST JT 2.375 BLAST JOINTS (2) 1.920 6,859.5 5,935.8 37.35 LOCATOR 2.675 BAKER LOCATOR MODEL G-22 1.965 6,860.3 5,936.4 37.37 SEAL ASSY 2.675 BAKER SEAL ASSEMBLY w/MULE SHOE 1.965 6,866.6 5,941.5 37.53 PACKER 3.968 BAKER 'DB' 32-26 PACKER 2.688 6,869.6 5,943.8 37.60 SBE 3.568 BAKER 40-26 SEAL BORE EXTENSION 2.688 6,880.7 5,952.6 37.87 NIPPLE 2.687 CAMCO 'D' NIPPLE 1.813 6,888.6 5,958.8 38.07 SOS 2.875 CAMCO SHEAR OUT SUB/WLEG. TTL ELMD @ 6875' ON SWS PPROF 8/30/1999 2.441 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) 4,563.0 4,124.8 37.85 CASING LEAK CASING LEAK - ARCHER ACOUSTIC LDL 5-19-18 5/19/2018 6.276 6,097.7 5,331.5 38.39 TUBING LEAK TUBING LEAK - HES LDL 3- 18-18, CONFIRMED W/ ARCHER ACOUSTIC LDL 5- 19-18 3/18/2018 2.992 6,335.0 5,517.5 38.63 CEMENT RETAINER FH 1-TRIP CEMENT RETAINER 005- 2725- 500 8/22/2023 0.000 6,931.0 5,992.1 38.55 FISH Lower Seal & Ring From Blanking Sleeve; Lost in Well 2/6/1989 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) 2,521.7 2,483.1 27.55 1 GAS LIFT GLV RK 1 1/2 1,257.0 3/14/2018 0.188 3,768.4 3,495.5 37.18 2 GAS LIFT OV RK 1 1/2 0.0 3/14/2018 0.188 4,763.6 4,283.8 37.41 3 GAS LIFT DMY RK 1 1/2 0.0 8/20/2010 0.000 2A-10, 11/3/2023 5:03:46 PM Vertical schematic (actual) LINER; 6,437.0-7,250.0 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 PACKER; 6,866.6 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 Cement Plug; 6,220.0 ftKB Packer; 6,183.6 GAS LIFT; 6,097.7 TUBING LEAK; 6,097.7 GAS LIFT; 5,602.6 GAS LIFT; 4,763.6 CASING LEAK; 4,563.0 GAS LIFT; 3,768.4 SURFACE; 35.0-2,862.7 GAS LIFT; 2,521.7 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB NIPPLE; 513.9 CONDUCTOR; 35.0-106.0 KUP PROD KB-Grd (ft) 35.01 RR Date 2/8/1986 Other Elev… 2A-10 ... TD Act Btm (ftKB) 7,260.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005600 Wellbore Status PROD Max Angle & MD Incl (°) 39.55 MD (ftKB) 5,800.00 WELLNAME WELLBORE2A-10 Annotation Last WO: End Date 8/20/2010 H2S (ppm) 150 Date 11/20/2015 Comment SSSV: NIPPLE 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) 5,602.6 4,947.1 38.65 4 GAS LIFT DMY RK 1 1/2 0.0 8/20/2010 0.000 6,097.7 5,331.5 38.39 5 GAS LIFT OPEN RK 1 1/2 3/7/2019 6,350.9 5,529.9 38.58 6 PROD DMY BK-2 1 0.0 7/24/1990 Close d 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,149.7 6,162.1 39.05 LANDING COLLAR 5.000 4.276 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,783.0 6,837.0 5,874.3 5,917.9 C-4, 2A-10 4/1/1986 12.0 IPERF 60 deg. ph; 3 3/8" HJ - II 6,892.0 6,902.0 5,961.5 5,969.4 A-4, 2A-10 4/1/1986 4.0 IPERF Gearhart 6,918.0 6,950.0 5,981.9 6,006.9 A-3, 2A-10 4/1/1986 6.0 IPERF 60 deg. ph; 3 3/8" HJ II Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,892.0 6,950.0 1 FRAC 10/15/1990 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,390.0 7,000.0 5,560.5 6,045.9 Cement Plug 8/22/2023 6,220.0 7,000.0 5,427.6 6,045.9 Cement Plug 8/22/2023 2A-10, 11/3/2023 5:03:47 PM Vertical schematic (actual) LINER; 6,437.0-7,250.0 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 PACKER; 6,866.6 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 Cement Plug; 6,220.0 ftKB Packer; 6,183.6 GAS LIFT; 6,097.7 TUBING LEAK; 6,097.7 GAS LIFT; 5,602.6 GAS LIFT; 4,763.6 CASING LEAK; 4,563.0 GAS LIFT; 3,768.4 SURFACE; 35.0-2,862.7 GAS LIFT; 2,521.7 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB NIPPLE; 513.9 CONDUCTOR; 35.0-106.0 KUP PROD 2A-10 ... WELLNAME WELLBORE2A-10 DTTMSTART JOBTYP SUMMARYOPS 8/26/2023 ACQUIRE DATA (PRE RWO) T X IA DDT (COMPLETE) 9/8/2023 ACQUIRE DATA (AC-EVAL) T-POT(PASS), T-PPPOT(PASS), IC-POT(PASS), IC- PPPOT(PASS) 9/26/2023 ACQUIRE DATA (PRE RWO) FT LDS/GN'S (COMPLETE) 10/1/2023 PUMPING TRACKING ONLY PUMP 15 BBLS METHONAL DOWN FL FOR FREEZE PROTECT 2A-10 10-404 Plug for Redrill Summary of Operations 6/30/2023 REPAIR WELL EQ & PULLED 2.72'' RBP @ 6232' RKB & GAUGES, PULLED EQ PRONG & 1.81'' CA-2 PLUG BODY @ 6881' RKB & GAUGES, SET 2.75'' BPC SLEEVE @ 6390' RKB, SET 2.72'' P2P RBP (OAL - 8') CE @ 6217' RKB, SET 2.77' AVA CATCHER ON TOP OF RBP @ 6209 'RKB. (C-SAND MAX BHP = 2276 PSI) (A-SAND MAX BHP = 2566 PSI) JOB COMPLETE 8/19/2023 REPAIR WELL PULLED 3.5" AVA CATCHER @ 6212' RKB, EQUALIZED 2.72" P2P RBP @ 6214' RKB. IN PROGRESS. 8/20/2023 REPAIR WELL PULLED 2.72" P2P RBP @ 6215' RKB, PULLED 2.75" AVA BPC @ 6390' RKB, MEASURED BHP @ 6350' RKB. READY FOR COIL ***SBHP 2355 PSI*** 8/21/2023 REPAIR WELL PERFORM WEEKLY BOP TEST. RIH W/ 1 TRIP CEMENT RETAINER. TAG AVA NIPPLE AT 6,390'. PICK UP TO 6,335' AND SET RETAINER. PUMP 29 BBL OF 15.8 PPG CLASS G CEMENT THROUGH RETAINER. LAY IN 1 BBL OF CEMENT ON TOP OF RETAINER. CLEAN DOWN TO DESIRED TOP OF CEMENT AT 6,220'. CHASE RETURNS TO SURFACE AND FREEEZE PROTECT TUBING. READY FOR TAG AND TEST IN 24HRS. 8/23/2023 REPAIR WELL TAG TOP OF CEMENT @ 6200' RKB, OBTAIN SAMPLE OF CEMENT. LDFN, JOB IN PROGRESS. 8/25/2023 REPAIR WELL PERFORMED CMIT TxIA TO 2500 PSI FAILED *SEE DETAILS IN LOG 10/15/2023 REPAIR WELL SPOT IN UNIT. CONDUCT WEEKLY BOP TEST. RIH W/ NOZZLE, TAG TOC AT 6180' CTMD (6200' RKB), PAINT FLAG AT 6150' RKB. RUN 3-1/2" TEST PACKER TO FLAG. SET TEST PACKER AT 6152' RKB, TEST FAILED. PICK UP AND RESET TEST PACKER AT 6134' RKB, 30 MINUTE MIT TEST PASSED. ***TAG AND MIT WITNESSED BY AOGCC SEAN SULLIVAN***. POOH. RDMO. 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 1 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 198-011/ T38554 179-059/ T38555 179-112/ T38556 183-020/ T38557 186-002/ T38558 201-083/ T38559 193-133/ T38560 203-099/ T38561 184-022/ T38562 183-095/ T38563 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 10:47:17 -09'00' 186-002/1 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Plug for Redrill Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7260'feet 6220', 6390'feet true vertical 6247'feet 6931'feet Effective Depth measured 6220'feet 6310', 6867',feet true vertical 5428'feet 5498', 5941'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-3/8" N-80/L-80 6889' MD 5959' TVD Packers and SSSV (type, measured and true vertical depth) 6184' MD 6310' MD 6867' MD N/A 5399' TVD 5498' TVD 5941' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 29 bbls 15.8 ppg Class G Cement thru retainer, 1 bbl on top of retainer. 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-329 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing: 6390-7000' , IA: 6390-7000' Packer: 47B2 FHL Packer Packer: Baker FHL Packer Packer: Bker DB 32-26 Packer SSSV: None Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718Well Interventions Engineer 6783-6837', 6892-6902', 6918-6950' 5874-5918', 5961-5969', 5982-6007' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Plugged for Redrill Gas-Mcf MD ~ Size 106' ~ ~~ Well was Shut-In ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-002 50-103-20056-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025570 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2A-10 Plugs Junk measured Length Production Liner 6655' 813' Casing 5799' 5" 6690' 7250' 6240' 2828' 106'Conductor Surface Intermediate 16" 9-5/8" 71' 2863' 2773' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:05 pm, Nov 07, 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: 2023.11.07 10:04:15-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor DTTMSTART JOBTYP SUMMARYOPS 3/29/2022 ANNCOMM DRIFT W/ 2.78" DMY WRP DOWN TO WRP @ 6226' RKB (NO ANOMALIES). JOB COMPLETE. 3/30/2023 ACQUIRE DATA DRIFT W/ 2.78" DMY TO WRP DOWN TO CATCHER @ 6226' RKB (NO ANOMALIES). JOB COMPLETE 6/1/2023 REPAIR WELL PULLED 3 1/2 AVA CATCHER @ 6226' RKB, EQUALIZED & PULLED 2.78 WRP @ 6229' RKB. IN PROGRESS. 6/2/2023 REPAIR WELL PULLED 2.75 AVA BPC @ 6390' RKB, BRUSH n' FLUSH 1.81 NIPPLE @ 6880' RKB (5 BBLS), SET 1.81" CA-2 PLUG & GAUGES @ 6880' RKB, SET 2.72" TTS RBP W/ GAUGES @ 6221' RKB (CE). IN PROGRESS 6/30/2023 REPAIR WELL EQ & PULLED 2.72'' RBP @ 6232' RKB & GAUGES, PULLED EQ PRONG & 1.81'' CA-2 PLUG BODY @ 6881' RKB & GAUGES, SET 2.75'' BPC SLEEVE @ 6390' RKB, SET 2.72'' P2P RBP (OAL - 8') CE @ 6217' RKB, SET 2.77' AVA CATCHER ON TOP OF RBP @ 6209 'RKB. (C-SAND MAX BHP = 2276 PSI) (A-SAND MAX BHP = 2566 PSI) JOB COMPLETE 8/19/2023 REPAIR WELL PULLED 3.5" AVA CATCHER @ 6212' RKB, EQUALIZED 2.72" P2P RBP @ 6214' RKB. IN PROGRESS. 8/20/2023 REPAIR WELL PULLED 2.72" P2P RBP @ 6215' RKB, PULLED 2.75" AVA BPC @ 6390' RKB, MEASURED BHP @ 6350' RKB. READY FOR COIL ***SBHP 2355 PSI*** 8/21/2023 REPAIR WELL PERFORM WEEKLY BOP TEST. RIH W/ 1 TRIP CEMENT RETAINER. TAG AVA NIPPLE AT 6,390'. PICK UP TO 6,335' AND SET RETAINER. PUMP 29 BBL OF 15.8 PPG CLASS G CEMENT THROUGH RETAINER. LAY IN 1 BBL OF CEMENT ON TOP OF RETAINER. CLEAN DOWN TO DESIRED TOP OF CEMENT AT 6,220'. CHASE RETURNS TO SURFACE AND FREEEZE PROTECT TUBING. READY FOR TAG AND TEST IN 24HRS. 8/23/2023 REPAIR WELL TAG TOP OF CEMENT @ 6200' RKB, OBTAIN SAMPLE OF CEMENT. LDFN, JOB IN PROGRESS. 8/25/2023 REPAIR WELL PERFORMED CMIT TxIA TO 2500 PSI FAILED *SEE DETAILS IN LOG 8/26/2023 ACQUIRE DATA (PRE RWO) T X IA DDT (COMPLETE) 9/8/2023 ACQUIRE DATA (AC-EVAL) T-POT(PASS), T-PPPOT(PASS), IC-POT(PASS), IC- PPPOT(PASS) 9/26/2023 ACQUIRE DATA (PRE RWO) FT LDS/GN'S (COMPLETE) 10/1/2023 PUMPING TRACKING ONLY PUMP 15 BBLS METHONAL DOWN FL FOR FREEZE PROTECT 2A-10 10-404 Plug for Redrill Summary of Operations 10/15/2023 REPAIR WELL SPOT IN UNIT. CONDUCT WEEKLY BOP TEST. RIH W/ NOZZLE, TAG TOC AT 6180' CTMD (6200' RKB), PAINT FLAG AT 6150' RKB. RUN 3-1/2" TEST PACKER TO FLAG. SET TEST PACKER AT 6152' RKB, TEST FAILED. PICK UP AND RESET TEST PACKER AT 6134' RKB, 30 MINUTE MIT TEST PASSED. ***TAG AND MIT WITNESSED BY AOGCC SEAN SULLIVAN***. POOH. RDMO. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,897.0 2A-10 12/2/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cement Job 2A-10 8/22/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE: WORKOVER w/TOP 2122' PROD CSG REPLACED/TBG COMPLETION REPLACED 9/4/2010 lmosbor NOTE: ***SURFACE ANNULUS CEMENTED FROM 2122' TO SURFACE*** 8/16/2010 lmosbor 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 35.0 106.0 106.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 35.0 2,862.7 2,773.3 36.00 J-55 BTC PRODUCTION 7" Tie- Back w/Patch 7 6.28 24.8 2,125.6 2,115.7 26.00 L-80 TCII PRODUCTION 7 6.28 35.0 6,690.1 5,799.2 26.00 J-55 BTC LINER 5 4.28 6,437.0 7,250.0 6,240.0 18.00 L-80 LTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 33.0 Set Depth 6,288.0 Set Depth 5,480.8 String Max No 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Mod 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) 33.0 33.0 0.00 HANGER 7.062 FMC 7 1/16" x 3 1/2" EUE TUBING HANGER w/ 3 1/2 Pup jt. FMC P#82- 747-236 2.900 513.9 513.8 1.41 NIPPLE 4.520 CAMCO 'DS' NIPPLE Camco "DS" 2.875 2,521.7 2,483.1 27.55 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 3,768.4 3,495.5 37.18 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 4,763.6 4,283.8 37.41 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 5,602.6 4,947.1 38.65 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 6,097.7 5,331.5 38.39 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 6,154.7 5,376.3 38.24 SEAL ASSY 3.980 SEAL ASSEMBLY/LOCATOR SUB w/ 80-40 Seals w/ 8' space out Baker 80-40 3.020 6,163.2 5,383.0 38.22 PBR 4.950 20-ft. x 80-40 PBR Baker 20' x 80- 40 4.000 6,183.6 5,399.0 38.16 Packer 5.970 7" 47B2 FHL Packer Baker 47B2 - 7" 26# 2.910 6,232.5 5,437.4 38.32 NIPPLE 4.520 CAMCO 'DS' NIPPLE Camco "DS" 2.812 6,277.2 5,472.4 38.61 SEAL ASSY 3.980 SEAL ASSEMBLY w/no seals / Spaced out 1' off fully located Baker 80-40 3.020 Top (ftKB) 6,287.1 Set Depth 6,889.3 Set Depth 5,959.4 String Max No 2 3/8 Tubing Description TUBING Original 3.5x2.375" Wt (lb/ft) 4.60 Grade N-80 Top Connection EUE BTC ID (in) 1.92 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) 6,296.6 5,487.6 38.73 PBR 5.125 BAKER PBR 3.000 6,310.4 5,498.3 38.72 PACKER 6.078 BAKER 'FHL' PACKER 3.000 6,350.9 5,529.9 38.58 PRODUCTION 5.390 CAMCO KBUG 2.920 6,390.3 5,560.7 38.45 NIPPLE 4.520 AVA BPL PORTED NIPPLE 2.310 6,393.2 5,563.0 38.44 XO 3.500 CROSSOVER 3.5"x2.875" 2.875 6,395.8 5,565.0 38.43 XO 2.875 CROSSOVER 2.875"x2.375" 2.375 6,786.8 5,877.3 35.92 BLAST JT 2.375 BLAST JOINTS (2) 1.920 6,859.5 5,935.8 37.35 LOCATOR 2.675 BAKER LOCATOR MODEL G-22 1.965 6,860.3 5,936.4 37.37 SEAL ASSY 2.675 BAKER SEAL ASSEMBLY w/MULE SHOE 1.965 6,866.6 5,941.5 37.53 PACKER 3.968 BAKER 'DB' 32-26 PACKER 2.688 6,869.6 5,943.8 37.60 SBE 3.568 BAKER 40-26 SEAL BORE EXTENSION 2.688 6,880.7 5,952.6 37.87 NIPPLE 2.687 CAMCO 'D' NIPPLE 1.813 6,888.6 5,958.8 38.07 SOS 2.875 CAMCO SHEAR OUT SUB/WLEG. TTL ELMD @ 6875' ON SWS PPROF 8/30/1999 2.441 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) 4,563.0 4,124.8 37.85 CASING LEAK CASING LEAK - ARCHER ACOUSTIC LDL 5-19-18 5/19/2018 6.276 6,097.7 5,331.5 38.39 TUBING LEAK TUBING LEAK - HES LDL 3- 18-18, CONFIRMED W/ ARCHER ACOUSTIC LDL 5- 19-18 3/18/2018 2.992 6,335.0 5,517.5 38.63 CEMENT RETAINER FH 1-TRIP CEMENT RETAINER 005- 2725- 500 8/22/2023 0.000 6,931.0 5,992.1 38.55 FISH Lower Seal & Ring From Blanking Sleeve; Lost in Well 2/6/1989 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) 2,521.7 2,483.1 27.55 1 GAS LIFT GLV RK 1 1/2 1,257.0 3/14/2018 0.188 3,768.4 3,495.5 37.18 2 GAS LIFT OV RK 1 1/2 0.0 3/14/2018 0.188 4,763.6 4,283.8 37.41 3 GAS LIFT DMY RK 1 1/2 0.0 8/20/2010 0.000 2A-10, 11/3/2023 5:03:46 PM Vertical schematic (actual) LINER; 6,437.0-7,250.0 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 PACKER; 6,866.6 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 Cement Plug; 6,220.0 ftKB Packer; 6,183.6 GAS LIFT; 6,097.7 TUBING LEAK; 6,097.7 GAS LIFT; 5,602.6 GAS LIFT; 4,763.6 CASING LEAK; 4,563.0 GAS LIFT; 3,768.4 SURFACE; 35.0-2,862.7 GAS LIFT; 2,521.7 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB NIPPLE; 513.9 CONDUCTOR; 35.0-106.0 KUP PROD KB-Grd (ft) 35.01 RR Date 2/8/1986 Other Elev 2A-10 ... TD Act Btm (ftKB) 7,260.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005600 Wellbore Status PROD Max Angle & MD Incl (°) 39.55 MD (ftKB) 5,800.00 WELLNAME WELLBORE2A-10 Annotation Last WO: End Date 8/20/2010 H2S (ppm) 150 Date 11/20/2015 Comment SSSV: NIPPLE 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) 5,602.6 4,947.1 38.65 4 GAS LIFT DMY RK 1 1/2 0.0 8/20/2010 0.000 6,097.7 5,331.5 38.39 5 GAS LIFT OPEN RK 1 1/2 3/7/2019 6,350.9 5,529.9 38.58 6 PROD DMY BK-2 1 0.0 7/24/1990 Close d 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,149.7 6,162.1 39.05 LANDING COLLAR 5.000 4.276 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,783.0 6,837.0 5,874.3 5,917.9 C-4, 2A-10 4/1/1986 12.0 IPERF 60 deg. ph; 3 3/8" HJ - II 6,892.0 6,902.0 5,961.5 5,969.4 A-4, 2A-10 4/1/1986 4.0 IPERF Gearhart 6,918.0 6,950.0 5,981.9 6,006.9 A-3, 2A-10 4/1/1986 6.0 IPERF 60 deg. ph; 3 3/8" HJ II Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,892.0 6,950.0 1 FRAC 10/15/1990 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,390.0 7,000.0 5,560.5 6,045.9 Cement Plug 8/22/2023 6,220.0 7,000.0 5,427.6 6,045.9 Cement Plug 8/22/2023 2A-10, 11/3/2023 5:03:47 PM Vertical schematic (actual) LINER; 6,437.0-7,250.0 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 PACKER; 6,866.6 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 Cement Plug; 6,220.0 ftKB Packer; 6,183.6 GAS LIFT; 6,097.7 TUBING LEAK; 6,097.7 GAS LIFT; 5,602.6 GAS LIFT; 4,763.6 CASING LEAK; 4,563.0 GAS LIFT; 3,768.4 SURFACE; 35.0-2,862.7 GAS LIFT; 2,521.7 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 CEMENT; 24.8 ftKB NIPPLE; 513.9 CONDUCTOR; 35.0-106.0 KUP PROD 2A-10 ... WELLNAME WELLBORE2A-10 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:14 Township:11N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:7260 ft MD Lease No.:ADL 025570 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 106 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 2863 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 6690 Feet Csg Cut@ Feet Liner:5"O.D. Shoe@ 7250 Feet Csg Cut@ Feet Tubing:3 1/2" x 2 3/8"O.D. Tail@ 6889 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bottom 7260 ft 6180 ft n/a C.T. Tag Initial 15 min 30 min 45 min Result Tubing 2550 2360 2305 IA 23 21 19 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: KRU 2A-10 has fullbore cement from 6390 ft MD to bottom. CTU tool string was 9.5 ft with down weight on tag 2000 lb. On initial set of test plug operator could not get a good seal. Pull 5 ft uphole and reset plug with good seal. Test Plug set above packer @ 6183 ft MD and below known leak @ 6097 ft MD. October 15, 2023 Sully Sullivan Well Bore Plug & Abandonment KRU 2A-10 ConocoPhillips Alaska Inc. PTD 1860020; Sundry 323-329 none Test Data: P Casing Removal: John Condio Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2023-1015_Plug_Verification_KRU_2A-10_ss 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 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): 7260'6931' Casing Collapse Conductor Surface Production 7" tieback w/patch 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 Adam Klem adam.klem@conocophillips.com (907) 263-4529 CTD/RWO Engineer Tubing Grade: Tubing MD (ft): Packer: 6184'MD/5399'TVD Packer: 6310'MD/5498'TVD Packer: 6867'MD/5941'TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 N-80 6288' 6889' 12/15/2023 Packer: Baker 47B2 FHL Packer: Baker FHL Packer: Baker DB SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025570 186-002 P.O. Box 100360, Anchorage, AK 99510 50-103-20056-00-00 ConocoPhillips Alaska, Inc. KRU 2A-10 None/SuspendedKuparuk Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6248' 6897' 5966' 1733 6220' 6390' MD 106' 2773' 2116' 106' 2863' 5799'6690' 2126' 16" 9-5/8" 71' 2828' Perforation Depth MD (ft): 7"2101' 6783-6837' (cement squeeze) 6892-6902' (cement squeeze) 6918-6950' (cement squeeze) 6655' 5" 5874-5918' 5962-5969' 5982-6007' 7250'813' 3-1/2" 3-1/2" x 2-3/8" 6240' 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:59 am, Sep 08, 2023 323-509 Adam Klem Digitally signed by Adam Klem Date: 2023.09.07 13:01:49 -08'00' SFD 9/19/2023VTL 10/4/2023 Re-enter Susp WellX DSR-9/11/23 10-407 BOP test to 3500 psig Annular preventer to 2500 psig X X *&:JLC 10/4/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.04 13:26:00 -08'00'10/04/23 RBDMS JSB 100523 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 7, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Staff RWO/CTD Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2A-10 (PTD# 186-002). Well 2A-10 was drilled and completed in 1986 as a Kuparuk A and C sand producer and the A sand frac'd soon after. It was re-frac'd in 1987, 1990 and 1993. It was worked over in 2010 for subsidence. In 2015, attempts to isolate the both the A and C sand failed indicating a leak in the selective. In 2018, it failed a TIFL, and both tubing and casing leaks were discoverd. Due to challenging selective completion and leaks in the tubing and casing, the well has been chosen as a canidate for redrill to access the same pool. A Frac Sundry will then be submitted, to support a fracture stimulation into the Kuparuk A-sand. If you have any questions or require any further information, please contact me at +1-907-263-4529 After a suspension of 2A-10 on a previously approved form 10-403 (sundry # 323-329), the tubing will be pulled, whipstock set. A permit to drill will be submitted seperatly to drill a short slant well to reacquire the Kuparuk A and C sands. A cemented 5.5" casing will be landed and lastly a 3 1/2" gas lifted upper completion will be installed. 2A-10 RWO Procedure Kuparuk Producer Sidetrack Setup PTD #186-002 Page 1 of 2 Completed Pre-Rig Work 1. Set plugs and gauges for SBHP of A and C sands – Completed 6/02/23 2. Suspend well based on separate state approved sundry (323-329)-Completed 8/23/23 a. Tag top of cement @ 6200’ MD Remaining Pre-Rig Work 3. T-PPPOT, T-POT, IC-PPOT, IC-POT tests 4. Dummy off GLMs 1 & 2 and leave station 5 open 5. Perform tubing cut at ~6180’ MD Rig Work MIRU 1. MIRU Nabors 7ES on 2A-10. Circulate well over to 8.5ppg seawater. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing, Set whipstock 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to cut (~6180’ RKB). 6. Set Whipstock at 6100’ TOWS oriented high side. Subsequent work to mill window and drill the 2A-10A sidetrack is covered in the Permit to Drill that will be submitted in parallel. 2A-10 RWO Procedure Kuparuk Producer Sidetrack Setup PTD #186-002 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen IV Tree, 3K rated casing flange Production Engineer: Marina Krysinski Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 12/15/23 Workover Engineer: Adam Klem (907 263-4529/ Adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre rig cut, set whipstock in preparation to drill 2A-10A lateral BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T failed due to tubing leaks CMIT-TxIA – failed due to casing leak IC POT & PPPOT planned pre rig TBG POT & PPPOT planned pre rig MPSP: 1733 psi using 0.1 psi/ft gradient Static BHP: 2277 psi/ 5437’ TVD (measured 7/1/23) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,897.0 2A-10 12/2/2015 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cement Job 2A-10 8/22/2023 famaj Notes: General & Safety Annotation End Date Last Mod By NOTE: WORKOVER w/TOP 2122' PROD CSG REPLACED/TBG COMPLETION REPLACED 9/4/2010 lmosbor NOTE: ***SURFACE ANNULUS CEMENTED FROM 2122' TO SURFACE*** 8/16/2010 lmosbor 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 35.0 106.0 106.0 62.50 H-40 WELDED SURFACE 9 5/8 8.76 35.0 2,862.7 2,773.3 36.00 J-55 BTC PRODUCTION 7" Tie- Back w/Patch 7 6.28 24.8 2,125.6 2,115.7 26.00 L-80 TCII PRODUCTION 7 6.28 35.0 6,690.1 5,799.2 26.00 J-55 BTC LINER 5 4.28 6,437.0 7,250.0 6,240.0 18.00 L-80 LTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 33.0 Set Depth … 6,288.0 Set Depth … 5,480.8 String Ma… 3 1/2 Tubing Description TUBING WO Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Mod 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) 33.0 33.0 0.00 HANGER 7.062 FMC 7 1/16" x 3 1/2" EUE TUBING HANGER w/ 3 1/2 Pup jt. FMC P#82- 747-236 2.900 513.9 513.8 1.41 NIPPLE 4.520 CAMCO 'DS' NIPPLE Camco "DS" 2.875 2,521.7 2,483.1 27.55 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 3,768.4 3,495.5 37.18 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 4,763.6 4,283.8 37.41 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 5,602.6 4,947.1 38.65 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 6,097.7 5,331.5 38.39 GAS LIFT 5.968 3.5" x 1.5" Camco "MMG" CAMCO MMG 2.920 6,154.7 5,376.3 38.24 SEAL ASSY 3.980 SEAL ASSEMBLY/LOCATOR SUB w/ 80-40 Seals w/ 8' space out Baker 80-40 3.020 6,163.2 5,383.0 38.22 PBR 4.950 20-ft. x 80-40 PBR Baker 20' x 80- 40 4.000 6,183.6 5,399.0 38.16 PACKER 5.970 7" 47B2 FHL Packer Baker 47B2 - 7" 26# 2.910 6,232.5 5,437.4 38.32 NIPPLE 4.520 CAMCO 'DS' NIPPLE Camco "DS" 2.812 6,277.2 5,472.4 38.61 SEAL ASSY 3.980 SEAL ASSEMBLY w/no seals / Spaced out 1' off fully located Baker 80-40 3.020 Top (ftKB) 6,287.1 Set Depth … 6,889.3 Set Depth … 5,959.4 String Ma… 2 3/8 Tubing Description TUBING Original 3.5x2.375" Wt (lb/ft) 4.60 Grade N-80 Top Connection EUE BTC ID (in) 1.92 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) 6,296.6 5,487.6 38.73 PBR 5.125 BAKER PBR 3.000 6,310.4 5,498.3 38.72 PACKER 6.078 BAKER 'FHL' PACKER 3.000 6,390.3 5,560.7 38.45 NIPPLE 4.520 AVA BPL PORTED NIPPLE 2.310 6,393.2 5,563.0 38.44 XO 3.500 CROSSOVER 3.5"x2.875" 2.875 6,395.8 5,565.0 38.43 XO 2.875 CROSSOVER 2.875"x2.375" 2.375 6,786.8 5,877.3 35.92 BLAST JT 2.375 BLAST JOINTS (2) 1.920 6,859.5 5,935.8 37.35 LOCATOR 2.675 BAKER LOCATOR MODEL G-22 1.965 6,860.3 5,936.4 37.37 SEAL ASSY 2.675 BAKER SEAL ASSEMBLY w/MULE SHOE 1.965 6,866.6 5,941.5 37.53 PACKER 3.968 BAKER 'DB' 32-26 PACKER 2.688 6,869.6 5,943.8 37.60 SBE 3.568 BAKER 40-26 SEAL BORE EXTENSION 2.688 6,880.7 5,952.6 37.87 NIPPLE 2.687 CAMCO 'D' NIPPLE 1.813 6,888.6 5,958.8 38.07 SOS 2.875 CAMCO SHEAR OUT SUB/WLEG. TTL ELMD @ 6875' ON SWS PPROF 8/30/1999 2.441 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) 4,563.0 4,124.8 37.85 CASING LEAK CASING LEAK - ARCHER ACOUSTIC LDL 5-19-18 5/19/2018 6.276 6,097.7 5,331.5 38.39 TUBING LEAK TUBING LEAK - HES LDL 3- 18-18, CONFIRMED W/ ARCHER ACOUSTIC LDL 5- 19-18 3/18/2018 2.992 6,335.0 5,517.5 38.63 CEMENT RETAINER FH 1-TRIP CEMENT RETAINER 005- 2725- 500 8/22/2023 0.000 6,931.0 5,992.1 38.55 FISH Lower Seal & Ring From Blanking Sleeve; Lost in Well 2/6/1989 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) 2,521.7 2,483.1 27.55 1 GAS LIFT GLV RK 1 1/2 1,257.0 3/14/2018 0.188 3,768.4 3,495.5 37.18 2 GAS LIFT OV RK 1 1/2 0.0 3/14/2018 0.188 4,763.6 4,283.8 37.41 3 GAS LIFT DMY RK 1 1/2 0.0 8/20/2010 0.000 5,602.6 4,947.1 38.65 4 GAS LIFT DMY RK 1 1/2 0.0 8/20/2010 0.000 2A-10, 8/22/2023 9:04:10 AM Vertical schematic (actual) LINER; 6,437.0-7,250.0 FLOAT SHOE; 7,248.4-7,250.0 FLOAT COLLAR; 7,199.0- 7,200.6 LANDING COLLAR; 7,149.7- 7,151.3 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 SOS; 6,888.6 NIPPLE; 6,880.7 SBE; 6,869.6 PACKER; 6,866.6 SEAL ASSY; 6,860.3 LOCATOR; 6,859.5 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 FLOAT SHOE; 6,688.4-6,690.1 FLOAT COLLAR; 6,599.7- 6,601.3 HANGER; 6,436.9-6,439.0 NIPPLE; 6,390.3 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 PBR; 6,296.6 SEAL ASSY; 6,277.2 NIPPLE; 6,232.5 Cement Plug; 6,220.0 ftKB PACKER; 6,183.6 PBR; 6,163.2 SEAL ASSY; 6,154.7 GAS LIFT; 6,097.7 TUBING LEAK; 6,097.7 GAS LIFT; 5,602.6 GAS LIFT; 4,763.6 CASING LEAK; 4,563.0 GAS LIFT; 3,768.4 SURFACE; 35.0-2,862.7 GAS LIFT; 2,521.7 Pup Joint; 2,511.6 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 Casing Patch; 2,121.4-2,125.6 Float Collar; 2,108.8-2,111.3 CEMENT; 24.8 ftKB NIPPLE; 513.9 CONDUCTOR; 35.0-106.0 HANGER; 33.0 KUP PROD KB-Grd (ft) 35.01 RR Date 2/8/1986 Other Elev… 2A-10 ... TD Act Btm (ftKB) 7,260.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032005600 Wellbore Status PROD Max Angle & MD Incl (°) 39.55 MD (ftKB) 5,800.00 WELLNAME WELLBORE2A-10 Annotation Last WO: End Date 8/20/2010 H2S (ppm) 150 Date 11/20/2015 Comment SSSV: NIPPLE 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) 6,097.7 5,331.5 38.39 5 GAS LIFT OPEN RK 1 1/2 3/7/2019 6,350.9 5,529.9 38.58 6 PROD DMY BK-2 1 0.0 7/24/1990 Close d 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,149.7 6,162.1 39.05 LANDING COLLAR 5.000 4.276 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,783.0 6,837.0 5,874.3 5,917.9 C-4, 2A-10 4/1/1986 12.0 IPERF 60 deg. ph; 3 3/8" HJ - II 6,892.0 6,902.0 5,961.5 5,969.4 A-4, 2A-10 4/1/1986 4.0 IPERF Gearhart 6,918.0 6,950.0 5,981.9 6,006.9 A-3, 2A-10 4/1/1986 6.0 IPERF 60 deg. ph; 3 3/8" HJ II Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 6,892.0 6,950.0 1 FRAC 10/15/1990 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,390.0 7,000.0 5,560.5 6,045.9 Cement Plug 8/22/2023 6,220.0 7,000.0 5,427.6 6,045.9 Cement Plug 8/22/2023 2A-10, 8/22/2023 9:04:11 AM Vertical schematic (actual) LINER; 6,437.0-7,250.0 FLOAT SHOE; 7,248.4-7,250.0 FLOAT COLLAR; 7,199.0- 7,200.6 LANDING COLLAR; 7,149.7- 7,151.3 IPERF; 6,918.0-6,950.0 FISH; 6,931.0 FRAC; 6,892.0 IPERF; 6,892.0-6,902.0 SOS; 6,888.6 NIPPLE; 6,880.7 SBE; 6,869.6 PACKER; 6,866.6 SEAL ASSY; 6,860.3 LOCATOR; 6,859.5 IPERF; 6,783.0-6,837.0 PRODUCTION; 2,122.0-6,690.1 FLOAT SHOE; 6,688.4-6,690.1 FLOAT COLLAR; 6,599.7- 6,601.3 HANGER; 6,436.9-6,439.0 NIPPLE; 6,390.3 Cement Plug; 6,390.0 ftKB PRODUCTION; 6,350.9 CEMENT RETAINER; 6,335.0 PACKER; 6,310.4 PBR; 6,296.6 SEAL ASSY; 6,277.2 NIPPLE; 6,232.5 Cement Plug; 6,220.0 ftKB PACKER; 6,183.6 PBR; 6,163.2 SEAL ASSY; 6,154.7 GAS LIFT; 6,097.7 TUBING LEAK; 6,097.7 GAS LIFT; 5,602.6 GAS LIFT; 4,763.6 CASING LEAK; 4,563.0 GAS LIFT; 3,768.4 SURFACE; 35.0-2,862.7 GAS LIFT; 2,521.7 Pup Joint; 2,511.6 PRODUCTION 7" Tie-Back w/Patch; 24.8-2,125.6 Casing Patch; 2,121.4-2,125.6 Float Collar; 2,108.8-2,111.3 CEMENT; 24.8 ftKB NIPPLE; 513.9 CONDUCTOR; 35.0-106.0 HANGER; 33.0 KUP PROD 2A-10 ... WELLNAME WELLBORE2A-10 2A-10 Proposed RST Schematic PROPOSED TIE-BACK CASING COMPLETION 5-1/2" 15.5# L-80 HYD563 SCC: 0'-6,700' 5-1/2"17# Hyd 521 6,700'-7,082' 5-1/2" Float Collar, float shoe PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE Tubing: 0'-6,760' 2.813" X nipple 3-1/2" Camco KBG 2-9 gas lift mandrels @ TBD HES TNT pack, VAMTOP 3.5" 9.3" TN-110SS Hyd 563 6,760'-6,900' 2.813" X nipple Baker CMU sliding Sleeve HES TNT pack, VAMTOP 2.813" X nipple WLEG 9-5/8" 36# J-55 shoe @ 2,863' RKB 5" 18# L-80 shoe @ 7,250' RKB 16" 62.5# H-40 shoe @ 106' RKB A-Sand Perf 6,892'-6,902' RKB 6,918'-6,950' RKB C-Sand Perf 6,783'-6,837' RKB 7" 26# L-80 shoe @ 6,100' RKB EOT ~6,888' 7" tieback @ 2125' RKB 7" casing leak @ 4,563' RKB RWOST KOP @ 6,100' MD RWOST TD 7" OH @ 7,082' MD RWOST A sand Perfs: 6,917'-6,923', 6,940-6,965' RWOST C sand Perfs: 6,814-6,866' HES 3.5"x5.5" TNT Packer: 6,710' HES 3.5"x5.5" TNT Packer: 6,890' 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): 7260'6931' Casing Collapse Structural Conductor Surface 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 Interventions Engineer Tubing Grade: Tubing MD (ft): 6184' MD and 5399' TVD 6310' MD and 5498' TVD 6867' MD and 5941' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80/ N-80 6889' 6/26/2023 Packer: 47B2 FHL Packer Packer: Baker FHL Packer Packer: Baker DB 32-26 Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025570 186-002 P.O. Box 100360, Anchorage, AK 99510 50-103-200560-00-00 ConocoPhillips Alaska, Inc. KRU 2A-10 N/A Plugged for RedrillKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6247' 6219' 5426' 6219', 6880' MD 106' 2773' 5799' 106' 2863' 6690' 16" 9-5/8" 71' 2828' Perforation Depth MD (ft): 7"6655' 6783-6837', 6892-6902', 6918-6950' 5" 5874-5918', 5961-5969', 5982-6007' 7250'813' 3-1/2" x 2-3/8" 6240' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:55 am, Jun 07, 2023 323-329 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: 2023.06.06 13:48:52-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor X MDG 6/12/2023 10-407 X Suspension expires 12/31/2023 DSR-6/12/23 20056 VTL 6/26/2023BWH 6/26/23 06/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.26 13:48:20 -08'00' RBDMS JSB 062723 Date: 5-30-23 Date of Work: 6-26-23 Subject: 2A-10 Reservoir Abandonment Prepared by: Katherine O’Connor (214) 684-7400 Well History 2A-10 is a gas lifted producer that has a casing leak and two tubing leaks. It has been mostly shut in since 2018. Fill cleanouts were attempted to get the well back online, but not successful overall. This well will be sidetracked and redrilled. The objective of this program is to abandon the reservoir in preparation for the sidetrack, which is scheduled for 30 August 2023. Notes: x Tubing leaks @ 6098’ RKB and 6436’ RKB (in the selective) x Casing leak @ 4563’ RKB x Last tag 2.78” 6226’ RKB (top of catcher) x RBP and BHP set 6/2/2023 at 6880’ RKB x Inclination Max: 39 deg @ 5700’ RKB x Min ID: 2.812” Camco DS Nipple @ 6232’ RKB x Last SBHP 10/15/2019 || 2411 psi || 7993’ RKB x Planned KOP for sidetrack ~5750’ RKB Calculations Procedure: Slickline 1. Pull plug and BHP gauge from ~6880’ RKB Coil 1. RIH with one trip cement retainer, set retainer @ ±6335’ RKB (middle of joint of tubing) 2. The total cement pumped is 27 bbls (25 below retainer and 2 above retainer) for planned TOC at 6100’ RKB. Recalculate cement volumes as necessary depending on retainer depth. 3. Pump the following cement schedule: a. ±10 bbl diesel to establish injectivity b. ±10 bbl freshwater spacer c. ±27 bbls 15.8ppg Class G cement 4. After 25 bbls pumped, unsting retainer and lay in the remaining 2 bbls into the tubing leaving TOC at ±6100’ RKB 5. POOH above TOC and circulate clean String Top Bottom Size Length ID bbls/ft volume ft/bbl notes 3.5" tubing 0 6393 3.5" 9.3# 6393 2.992" 0.0087 55.6 115.0 tally depth 2-3/8" tubing 6393 6889 2-3/8" 4.6# 496 1.92" 0.00358 1.8 279.2 tally depth 3.5" x 7" annulus (IA) 0 6183 3.5" 9.3# x 7" 26# 6183 6.28" x 3.5" 0.0264 163.3 37.9 uppermost packer 5" liner 6437 7250 5" 18# 813 4.28" 0.0178 14.5 56.2 The objective of this program is to abandon the reservoir in preparation for the sidetrack, which is scheduled for 30 August 2023. 6. RDMO Slickline & Fullbore 1. WOC for minimum 24 hours. Notify AOGCC inspector of cement timing and plug tag at least 24 hours in advance. 2. RU Slickline and PT equipment as required 3. RIH to tag TOC (AOGCC witness) @ approx. 6100’ RKB, record results 4. CMIT-TxIA to 2500 psi (AOGCC witness), record results Planned TOC 6100’ RKB WELL LOG TRANSMITTAL #904720553 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Set Record: 2A-10 Run Date: 3/7/2019 186002 30 73 3 April 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20056-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS ANC@halliburton.com ,te: Signed: RECEIVED MAY 0 8 1019 AOGCC 18602 • WELL LOG TRANSMITTAL#904720553 29378 To: Alaska Oil and Gas Conservation Comm. June 11, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 2 0 2018 RE: Leak Detect Log: 2A-10 AO�7n�� Run Date: 3/18/2018 The technical data listed below is beingsubmitted herewith. Please address anyproblems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-10 Digital Data in LAS format, Digital Log file 1 CD Rom 50-103-20056-00 Leak Detect Log 1 Color Log 50-103-20056-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANS JUN 2'5 LU i4 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Lp/2iP- Signed: i • . CU tV �, rrrrr rr V. ~ >' ilb r r r r x No ? u, Q 0 �� N L O + O (D O •C U N 4- > , N O CO (o +. v) N O ( C C C +., J a Q W 4.) 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(0 000D00000 i � , da ❑ aodchv> v> ch <n 4) mmamamU) voivv)i0cn B N CC W G O ❑ CI C) 10 CI ❑ ❑ C O IX x ^ U c ro (n 0 ( H- O 0 o 0 0 0 0 0 0 0 0 0 C O O O O o 0 0 0 0 0 0 bA .y c. <cocov v) El O u) u) N- h N U) v) O O) M L O M # r 0 N 0 N N- N )n in .. 1'� N 0 M 0 M O N N N M M O NaI N N NNNNNN N N N R Q O) M M O M O O O ) O) O) O) N ) a) EO N 0 N 0 N 0 N N N N N '� O r O O O O O O O 7 OO O O O O O O O O O +a O a) Oco C u.) u) (n (n in N (n u) N In N p, y CO Eo, E a) Y W Y O '`..W ct 1 C jr_C CID U a Q O 2 co 7 a 'a 'Q N aj H Q M o a V O o O O) V. }, I OJ In 01 Z s.+ op fY( :Z N r O N N N r . r +' H t. = C2 cn _, —1 Q P s cn O O s s s `° a C a Q O N r N M M M M T r. r. Z G! RS U ^ f6 C d ra OCID a a � 1= a`aE. Q WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch: 2A-10 Run Date: 8/8/2010 August 20, 2010 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 2A-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20056-00 .-` `' 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.woo -~ ;, . Date: ~G'~?c ~r--. 1 ~~ _~~ a ~®as.~' Signed: ,,a~ PeoAcrive DiAgnosric SeRVicES, Imo. ~L~ L+~l~ ~~~~~~~ • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTJ The technical data fisted below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the foffowing ; ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 ] Caliper Report 10 Aug-10 2A-10 1 Report /EDE 50-103-20056-00 2J Correlation Log 10-Aug-10 2A-10 EDE 50-103-20056-00 ~~/ l.0 ~ D~ ~~ Signed Print Name: ~ ; ~ - ~ ~ ~~ t -~ ~ , ;_ ~, ate ~ !e; ~ A M1 _.... 9....s, J ~~ ° PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~Sl~~e'1&'9~~i08'~p~l~s°3~1°4'c'O~°B$~Cd.~i3ia'9 WEBSITE : sA~`'DIi~Y..Y~".ES'9?t3~tp~4Ca".t~~13 C:\Documents and Settings\Diane Williams\Desktop\Transmit_Conoco.docx • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: String Shot: 2A-10 Run Date: 8/11/2010 August 12, 2010 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 2A-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20056-00 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.wo i Date: AUG ~ ~ ~01C ~F 19as ~~ ~~~~~a q ~~ Signed: • • ~~p~C~ OCR aC~Q~I~Q /~..a~Ew~o~,~. Howard Gober Wells Engineer ~~ ConocoPhillips Alaska, Inc. , , ~ z ,~ l~j~~[~ ~ ~„ -~ P.O. Box 100360 :*~..~.4s w~~ ' `` "` ~~~ ~ lS/ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-10 Sundry Number: 310-222 Dear Mr. Gober: 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, Daniel T. Seamount, Jr. Chair DATED this2-7day of July, 2010. Encl. • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 21, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: • ~U~ 2 2 2010 ~~~~ki~ ~ ~~ C~i~. ~+- ~'SSIUtI ~`,fiC~`i?~t~~~ ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2A-10 (PTD 186-002). 2A-10 was originally completed in 1986. The well is a selective single gas lifted producer located in an area with surface subsidence. The well had been on-line as a gas lifted producer utilizing 2 POGLM's (packoff gas lift mandrels) in the tubing string. Periodic drifts were being performed to ensure the POGLM's could be pulled from the well. The drift run in October of 2009 encountered a tight interval at 800', so the POGLM's were pulled. Since the tubing had been perforated where the POGLM's were set, we could no longer produce the well. The well was secured with a WRP below the top packer on 11/2/09. After setting the plug, the well passed a CMIT TxIA to 2200 psi. It also passed a drawdown test. A passing MITOA to 1800 psi was obtained on 9/23/09. • Prior to setting the WRP, a SBHP was obtained on 10/26/09. The pressure within the lower A sand perfs was measured at 2,534 psi at a depth of 6,930' MD (5,992' TVD) which equates to 8.5 ppg KWF with a 125 psi overbalance. We will use 9.6 ppg brine as a KWF during the workover. The MASP is 1,935 psi based upon the SBHP data. The objective of this workover is to replace the corkscrewed/buckled tubing, cut & pull a portion of the 7" casing, re-run new 7" casing, and circulate cement into the 9-5/8" x 7" annulus. The 7" casing work is not required to fix an existing problem, but it will be done while the rig is on the well as a proactive measure. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Gob r Wells Engineer CPAI Drilling and Wells STATE OF ALASKA ALAS~ILAND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ~ Plug for Redrill "" Perforate New Fool I"`" Repair well - Change Approved Program ~"' Suspend ~ Plug Perforations Ft'rforate Pull Tubing ~! Time Extension C+perational Shutdow n Re-enter Susp. Well ~ Stimulate ARer casin g ~ •Other: ~""` 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~, Exploratory 186-002 3. Address: Stratgraphic ~` Service ~""" 6. API Number: P. O. Box 100360, Anchors e, Alaska 99510 50-103-20056-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes No 2A-10 ' 9. Property Designation: 10. Field/Pool(s): ADL 25570 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7260 6248 7094' 6118' 6330' 6931' Casing Length Size MD ND Burst Collapse CONDUCTOR 106 16 106' 106' SURFACE 2863 9.625 2863' 2774' PRODUCTION 6690 7 6690' 5800' LINER 813 5 7250' 6241' Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6783'-6837', 6892'-6902', 6918'-6950' 5875'-5919', 5962'-5970', 5983'-6007' 3.5, 2.375 J-55, N-80 6395', 6885 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER'FHL' PACKER MD= 6310 TVD= 5498 PACKER -BAKER 'DB' PACKER MD= 6861 TVD= 5937 CAMCO'TRDP-1A-SSA' MD= 1803 TVD= 1801 12. Attachments: Description Summary of Proposal J 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~°"` E~loratory ~'•"'` Development ~` Service ~" 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/2/2010 Oil Gas WDSPL Suspended 16. Verbal Approval: Date: WINJ r GINJ WAG Abandoned ~"'" Commission Representative: GSTOR I~ SPLUG ~` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Engineer / ~l Z D t l 1 / ~ Signature .. e a Phone: 263-4220 (. Cm in nl Sundry Number: 31 ~ `Ci Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test Mechanical IntegrityTest ~' Location Clearance 3~~ Psi QoP s ~ ~~~~~VED \ Other: *'Z SG ~~tn~ ~-S~ Cv~-+.. J S.Ad . P L p t F rm R S b i d I ~ (~h~ ~~~ ~~ r ~~ r~~ 2 o f~-~4-~-- 25. ~~~ ~ 2010 ~~ u sequen o equ re : / ~ lk~l ~ gl GSS COt3z. CtimmISS10 ~~~ ~ v -- ~/ 0 { , ~-iiC~f'JtB~~ APPROVED BY '''7 Z /~ Approved by: COMMISSIONER T COMMISSIO N Date: / Form 10-403 Revised 1/2010 ~ t~ Submit in Duplicate ~ G I N A ,~~- ~~z~ ~ z~~ r ~- l-v--~` ~, KUP • 2A-10 t~t,_ ~C?('9C>~C3~i ti~~}pc~ ,_. , `=' 7~ ', ' Well Attributes Max Angle & MD ° iTD B ~` I W ellbore APUD WI (Field Name ) MD (ftKB) Well Status Inc! ( ( Act tm (ftKB) '~-' ~ m 501032005600 PROD 39.55 5,800.00 KUPARUK RIVER UNIT 7260.0 ( Comment H25 (ppm) End Date KB-Grd (fi) Date IAn otation RigR I ase Date ••' I SSSV: LOCKED OU I T 400 / 1/10/2009 Last WO: 35 07 2/8!1986 W¢Il Cbnfi~ 2A 1Q, 14 Sdtemat A c , ul u.~i I Annotation 'De th ftKB End Date ) - Annotation Last Mod 8 Entl Date _ Last I aq: SLM I 6 902.0 10/77!2009 ( Rev Reason: Set WRP, Delete Waiver Note Imosbor ~ 7114/2009 Casin Strin s _ Strin OD Strin ID 9 9 Set De th P Set Depth ND) i String W[ Strmg l "" -~"' Casing Description (in) (in) Top (HKB) (ftKB) (ftKB) (Ibs/H) G de- Str g Top Thrd v CONDUCTOR 060 161 15 00 106.0 106.0 62.SOIHdO coNDUCroR._ . 166 , SURFACE 95/8 8.765 00 2,863.0 2,774.0( 36.OOJ-55 ~- (, PRODUCTION I 71 6.151 0.0 6,690.0 5,799.5' 26.00 J-55 ( sAFEnvtv._ _. -- .. _ I, ' LINER 4151 , L-80 6,437.0 7,250.0 6,240.51 18.00 - L803 T I Stn 5 U g g I. _1 _- __- _- - ___-. __ P b stun oD g ' Str ng ID Set Depth Set Depth (ND) String Wt String C Tubin D scri lion (in) (In) Top (ftKB) (HKB) (ftKB) (Ibs/ft) Grade String Top ThM SURFACE, _.. _ _ _ L ~ 3 1 2 2 992 0.0 6,395.0 5,564.9 9.30 J 55 8RD ABM 2,863 , TUBING 2318 1995 6,395.0 6,885.0 5,956.5 470 N-80 EUE SRD f I _.. _. _. ___.. _- ______- t Other In Hole All Jewel :Tubin Run & Retrievable, Fish, etc.) Top Depth GAS LIFT. _.. p Top Inc! 6.257 A,~ ) rnp f ftKB (°) I Description Comment Run Dafe ID 4in)_ E I ° 1 t803 1,801.1 8.78 SAFETY VLV Camco'TRDP-tA-SSA' (Locked Out on 10/8/97) 3/23/1986 2.813 I 6,257 5,4572 38 89 GAS LIFT CAMCO/MMG-2l1/DMYlRK/I/ Comment: STA 1 3123!1986 2.922 6,297 5488.3 38.76 PBR Baker PBR 3(2311986 3.000 PeR, fi.zsT 6,370 5,498.4 38.72 PACKER iBaker'FHL' PACKER 3/23/1986 3.000 6,330 _ 5,514.1 38.65 PLUG .. _- _ WRP 11/2/2009 0000 6,351 5,530.5 38.58 PRODUCTION CAMCOIKBUG/11DMY/BK-2/// Comment: CLOSED STA 2 7/24/1990 2 875 ~ ~~ 6,390 5,561.0 3845 NIPPLE AVA BPL PORTED NIPPLE 3/23/1986 2.750 PACKER, 6.310-- -._.~ . 6,390 5,561.0 3845 SLEEVE C -_ AVA 2.75" BPI SLEEVE _- - 10/17/2009 2.313 :: :a 6,861 5,937.6 38.10 PACKER Baker'DB' PACKER 3/23/1986 2.688 I i 6,875 5,948.6 38.19 NIPPLE _ GamCO 'D' Nipple NO GO 3/23/1986 1.813 I I 6,883 5,9549 I 3824~ __ SOS __ _. Camco __. 3!23/1986 -._-. 1.995 PL UG.6 330 6 884 5,955.7 ~ 38 25 TTL - - - ELMD @ 6875' ON S WS PPROF 8/30/7999 3123/1986 - 1.995 ' ~, 6,931 5.992) 38 97 FISH Lower Seal & Rmq From Blanking Sleeve; Lost in Well 2!6!1989 I I I _- -_ __ ~ Perfora dons & Slots PRODUCTION h t ---- , 6,351 ~~ ~ ~ Top (TV D) Btm (ND) p I " Top (k KB) Btm (ftKB) ' (ftKB) (ftKB) Zone Date l h Type C M j ;8 6,783 6,837 _ 1 5,874.7 5.918.6 C -4, 2A-10 4/1/1986 12 0 IPERF 60 deg. ph; 3 3/8" HJ - II ! 6,892 6,902 ', 5,962.0 5,970.1 A -4, 2A-10 4/1/1986 401PERF Gearhart NIPPLE,6390 SLEEVE-c. ~ _- 6 396 ~' - 6,918 6 950 - 5 982.6 6,007.4 A -3, 2A-10 ' 4/1!1986 6 0 IPERF -- 60 deq. ph; 3 3/8" HJ II . ' Notes: General & Safet _ End Date Annotation _ 10/17;2009 NOTE: TBG PERFS @ 2722' RKB & 4136' RKB (see 9/21/05 & 9178/05 WSRS) PRODUCTION, -. _ f 6,690 IPERF. - - -- --- .- -- L 6,]83-6,837 - l PACKER, 6,861 - - _,~ . I{ J _ NIPPLE, fi.B]5--- ------- I F- i~ SOS, 6,883-- ~+ TTL. 6.886 -.. IPERF, A y1 6,892-6,502 `{ ~ ~~ FISH. 6,931 - - - IPERF, _ 6,918-6,950 LINER, ],250 - TD, ],260 ~- 2A-10 Expense Rig Workover (PTD #: 186-002) Current Status The well is currently shut in awaiting a Workover to replace the corkscrewed tubing that has been perforated and proactively repair the 7" production casing. This well is located in an area with surface subsidence. Due to the corkscrewed tubing, we had to proactively pull the POGLM's (packoff gas lift mandrels) that were in the well. A WRP has been set below the top packer. I has passed a pressure test and a drawdown test. The production casing and surface casing currently pass pressure tests. Scope of Work Pull the tubing, proactively cut & pull a portion of the 7" casing, re-run new 7" casing, circulate cement into the 9 5/g" x 7" annulus, and run new 3-1/2" tubing. General Well info MASP: 1,935 psi ° Reservoir pressure/TVD: 2,534 psi / 5,992' TVD (10/26/09) Wellhead type/pressure rating: FMC KRU Ge~,~11" 3K btm x 7-1/16" 5K top flange BOP configuration: Annular /Pipe Rams /Blind Rams /Mud Cross /Pipe Rams CMIT / MITOA results: CMIT TxIA-passed on 11/02/09, MITOA-passed on 9/23/09 Well Type: Producer Estimated Start Date: August 2, 2010 Production Engineer: Mike Balog /Evan Reilly Workover Engineer: Howard Gober (263-4220 / howard.gober@conocophillips.com) Pre-Rig Work 1. RU Slickline: Set catcher sub on top of WRP. Pull DV in GLM @ 6,257' MD 2. Load hole with 9.6 ppg brine if time allows. 3. Bleed tubing, IA, and OA to 0 psi. 4. Set BPV. Proposed Procedure 1. MIRU Nordic 3. 2. Pull BPV. Circulate 9.6 ppg brine through open mandrel at 6,257' RKB if not done pre-rig. Verify well is dead. Set BPV. ND tree. Install FMC blanking plug in lift threads. NU 11" 5M BOP and adapter spool. Pressure test BOP including annular to 250/3000 psi. Maximum potential surface pressure is calculated to be 1,935 psi based upon the SBHP obtained on 10/26/09 and using a 0.1 psi/ft gas gradient. 3. Pull blanking plug and BPV. Circulate hole clean. Pull and lay down tubing. A. If tubing does not pull free, set tubing in tension, RU E-line and cut tubing at +/- 6,280' RKB.' POOH laying down tubing 4. Run 7" scraper on drillpipe to top of tubing stub. Circ hole clean. POOH. 5. RU E-Line: Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. Based on cement top, determine depth of 7" collar to back off following casing cut. RIH and fire string shot across that collar. RD E-Line. 6. Set RBP or IBP below top of cement. Pressure test to 2500 psi and drawdown test to 0 psi. 7. RIH w/ muleshoe on drillpipe and spot 50' of sand on top of RBP/IBP. POOH. 8. RIH with drill collars, install storm packer and hang off in 7" casing below surface (to reduce casing compression at the wellhead). 9. ND BOP, install long all-thread bolts on wellhead. Begin ND tubing head allowing 7" casing to grow. 2A-10 Expense Rig Workover (PTD #: 186-002) Proposed Procedure Continued 10. Remove tubing head and packoffs. 11. Spear 7" csg and pull in tension and re-land in slips. Tack weld slips to casing cut off casing so it does not interfere with BOP stack. ~ 12. NU 11" 5M BOP on casing head. Change out lower rams to 7". Pressure tes The test pressure will be acting against the surface casing since the 7" pac o 13. Retrieve storm packer. • 14. RIH w/multi-string cutter and cut 7" casing above TOC. , RU Wachs cutter and o (c t BOP t0 SI. (/csritK ~-~- as been removed. ~ S:sh.~Q~~ ~,~- 7`Z~ /`~ 15. Circulate out Arctic Pack in the 9 5/" x 7" annulus using hot diesel followed by hot seawater. 16. Spear and POOH laying down 7" casing. 17. Change lower pipe rams back to VBR's and test to 250/3000 psi. 18. Run 9-5/8" casing scraper to top of 7" stub. Circulate clean. • 19. RU E-Line: Run GR, caliper, and gyro in 9-5/8" casing. RD E-Line. 20. Run back off tool and back off casing stub. 21. Run tandem string mills to gauge the 9 5/e' csg for the ES cementer. 22. Make a dummy drift run for the 7" casing & ES cementer. . 23. Spear and recover backed off 7" casing stub. • 24. Change lower pipe rams to 7". Pressure test BOP to 250/3000 psi. ~~ 25. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. PT casing to 3000 psi. 26. Open ES cementer and pump cement into 9-5/8" x 7" annulus. If a hole was milled in the surface casing, close the IA once cement returns at surface and squeeze cement into SC leak. Continue to pump cement until plug closes cementer. WOC. 27. ND BOP, pull 7" casing in tension and land in slips. Cut excess 7" casing and install packoff. NU new tubing head. 28. NU 11" 5M BOP, change out lower pipe rams to VBR's. PT rams and break to 250/3000 psi. 29. Drill out cement and ES cementer down to top of sand. Pressure test casing to 2500 psi. + 30. RIH w/ reverse circulating junk basket and string magnets to clean up wellbore. 31. RIH w/ retrieving tool on work string. Release RBP/IBP and POOH laying down drill pipe. 32. RIH with remaining drill pipe and POOH laying down 33. RIH with new 3-1 /2" tubing and seal assembly. Circulate well full of corrosion inhibited fluid. Stab into PBR, space out and land. Pressure test tubing and IA to 3000 psi. Shear SOV. 34. Set 2-way check. ND BOP. NU tree and pressure test. 35. Pull 2-way check. Freeze protect well. Set BPV. 36. RDMO Nordic 3. Post Rig Work / 1. RU Slickline: Pull SOV and run new gas lift design, pull catcher sub and WRP. / 2. Return well to production. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2A-10 Run Date: 10/27/2009 December 1, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20056-00 ~y: ~ F h ~ ,~ ~ G ~ ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto `~(o -bb o~ 6900 Arctic Blvd. Anchorage, Alaska 99518 ~ ~ ~l.~ Office: 907-273-3527 Fax:907-273-3535 ~. rafael.barreto cow ~. !'~ ~t _ i ~ EC ~ ~ 2000 Date: Signed: 0'tE x~ ~~ res. t~c~r~ ~ a c .. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2A -10 Run Date: 10/27/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 20056 -00 1,�a'��jj'�f�''^"'+' NC} 1 2009 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto —06D 6900 Arctic Blvd. 6, Anchorage, Alaska 99518 1 0 93? Office: 907 273 -3527 Fax: 907 273 -3535 rafael.ban Date: NOV tp 6 ;3f1Pr4 Signed: _. _ ,- ,~,~ ~ r Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 tt~~~lR~~ SEC ~: ~ ZOD7 Dear Mr. Maunder: • Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCG, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitorlsealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor s • Surface Casing by Conductor Annuius Cement, Corrosion inhibitor, Sealant fop-off Report of Sundry Operations (10-404) Data Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12/14/2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 12/5/2007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14/2007 2A-08 185-248 SF na SF na 3 12/5/2007 2A-09 186-001 SF na SF na 1.'75 12/14/2007 ZA 10 1.86-002 23' 3.1 ~ 11" 9/2412007 7 12I5i2iiQ7 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9/24/2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5/2007 2A-1O TIFL -failed . . Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, September 19,20077:33 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF2 Prod Engrs; CPF2 DS Lead Techs NSK Subject: 2A-10 TIFL -tailed Attachments: 2A-10 schematic. pdt; 2A-10 90 DAY TIO.git ,~ ç¡·/lq (07 K..,ø f1 ' Tom & Jim, ~ b...ùor \ g..1\"'lO Kuparuk gas lifted producer 2A-10 (PTD 1860020) tailed a TIFL on 09/18/07 and has been added to the SCP report. The TIO immediately prior to SI tor the TIFL was 175/1350/1200. A leaking GLV is suspected. Slickline will trouble shoot the tubing leak and repair it possible. ..,/ Attached is a schematic and 90 day TIO plot. «2A-10 schematic. pdt» «2A-10 90 DAY TIO.git» Please let me know it you have any questions. Perry L. Greenwood Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 5CANNEC' SEP 2 12007 9/19/2007 21-JUN-01 01:26 WEEK SCRATCH 53 FLOW TUBING PRESSURE "I?????? HI OPERATOR OPERATOR VERIFIED SCRATCH_53 OUTER BOTH EVENTS SUM: RECORDING SUMMARY WELL GUIDELINES file:lllCj/templYemporary Internet F*slOLK24/2A-JO 9û DAY Y!O.gíf91!9/2007 7:56:31 AM . . KRU 2A-10 API: 501032005600 Well Tvpe: PROD Angle (âJ TS: 36 deg (âJ 6782 SSSV Type: Locked Out Orig 2/8/1986 Angle @ TD: 39 deg @ 7260 sssv Completion: (1803-1804, Annular Fluid: Last W/O: Rev Reason: ADD TTL ELMD 00:3.500) Reference Loa: Ref Loa Date: Last Update: 9/7/2007 Last Taa: 6827 TD: 7260 ftKB TUBING Last Taa Date: 5/18/2005 MaxHoleA~5800 (0-6395, 00:3.500. Descriotion Size Too Bottom TVD Wt Grade Thread 10:2.992) CONDUCTOR 16.000 0 106 106 62.50 H-40 SUR CASING 9,625 0 2863 2774 36.00 J-55 PROD CASING 7.000 0 6690 5800 26.00 J-55 LINER 5.000 6437 7250 6240 18.00 L-80 I Size Too I Bottom TVD Wt Grade I Thread I 3.500 0 I 6395 1 5565 1 9.30 I J-55 I 8RD ABM I 1 2.375 6395 I 6885 1 5956 1 4.70 1 N-80 1 EUE 8RD I , Interval TVD Zone Status Ft SPF Date Tvoe Comment Gas Lift 6783 - 6837 5875 - 5918 C-4 54 12 4/1/1986 IPERF 60 deo. ph' 3 3/8" HJ - II .ndreVDummy 6892 - 6902 5962 - 5970 A-4 10 4 4/1/1986 IPERF Gearhart Valve 3 (6257-6258, 6918 - 6950 5982 - 6007 A-3 32 6 4/1/1986 IPERF 60 ¡tit 3/8" HJ II 00:5.750) 51 MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TR ate Run Vlv PBR Cmnt (6297-6298, 1 2718 2654 POGLM GLV 1.0 0.188 1301 9/21/2005 (1) 00:3.500) 2 4242 3873 POGLM OV 1.0 0.250 0 9/19/2005 3 6257 5457 CAMCO MMG-2 DMY 1.0 RK 0.000 0 3/23/1986 1. 2 PACKOFF GAS LIFT MANDRELS (POGLM) ASSEMBLIES, FROM TOP DOWN. CONSIST OF SLIP STOP, BAKER K3 PACKOFF, SPACER PIPE, CONCENTRIC GAS LIFT MANDREL (WITH A TBG PERF AT EACH GLM DEPTH), SPACER PKR PIPE, BAKER K3 PACKOFF, AND HES F-COLLAR STOP A T BOTTOM (6310-6311, OD:6.078) 51 MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 2 1 6351 55311 Cameo 1 KBUG I Merla 1 DMY I 1.0 1 BK-2 0.000 I o 17/24/1990 (1) 1. CLOSED Production .ndn3ll0ummy DeDth TVD TVDe DescrlDtlon ID Valve 2 1803 1802 SSSV Cameo'TRDP-1A-SSA' (Locked Out on 10/8/97) 2.813 (6351-6352, OD:5.313) 6297 5488 PBR Baker 3.000 6310 5498 PKR Baker 'FHL' 3,000 SLEEVE-O 6390 5561 SLEEVE-O AVA 2.75" BPC SLEEVE set 4/3/2004 2.313 (6390-6391, 6390 5561 NIP AVA BPL PORTED NIPPLE 2.750 00:2.750) 6861 5937 PKR Baker 'DB' 2.688 6875 5948 NIP Cameo 'D' Nipple NO GO 1.813 6883 5955 SOS Cameo 1.995 Perf - - 6884 5955 TTL ELMD ía) 6875' ON SWS PPROF 8/30/1999 1.995 (6763-6837) .......... ----- - .m.. I DeDth 1 DescriDtlon I Comment - - I 6931 I'" ~ TUBING (6395-6885, 00:2.375, Date 10:1.995) I Note 1/18/2002 NOTE: WAIVERED WELL -IA x OA ANNULAR COMMUNICATION LINER (6437-7250, 00:5.000, Wt:18.OO) SOS (6863-6884, 00:2.375) TTL (6884-6885, 00:2.375) Perf .......... (6892-6902) ..... ....... ..... - - Perf (6918-6950) - - - - - - Lower Seal ------ Ring ..... m..... (6931-6932, - - 00:2.000) ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 ~_.... October 25, 2005 [:!)E " " !! "" i",,,x~ (, E , VE [) OCT 2 7 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 8¡, Cons.. Commission lmch~¡n~ge Subject: Report of Sundry Well Operations for 2A-10 (APD 186-002) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation activity on the Kuparuk well 2A-10. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 1{4~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells ~^",NE\) OCi 31 ?tlí:l5 M M/skad ) ) RECEIVED STATE OF ALASKA 05 ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 8 20 REPORT OF SUNDRY WELL OPERA TIONiaska 0" & Gas Cons. Commission 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other Aru::~age Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operato,r Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 186-0021 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20056-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 123' 2A-10 8. Property Designation: ADL 25570, ALK 2668 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth measured 7260' 6248' Casing Structural CONDUCTOR SUR CASING PROD CASING LINER Length Size feet feet 6827' feet feet MD 106' 2863' 6690' 7250' Plugs (measured) Junk (measured) true vertical Effective Depth measured true vertical TVD Burst Collapse 106' 2828' 6655' 813' 16" 9-5/8" 7" 5" 106' 2773' 5799' 6239' Perforation depth: Measured depth: 6783'-6837', 6892'-6902', 6918'-6950' 4136', 2722' (perf. Tubing) true vertical depth: 5875'-5918',5962'-5970',5982'-6007' 3790', 2657' Tubing (size, grade, and measured depth) 3.5" 12-3/8", J-55/ N-80, 6395' /6885' MD. SCANNEri) OCT 3 1 2005 Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'DB' pkr= 6310'; 6861' SSSV= Cameo 'TRDP-1A-SSA' SSSV= 1803' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS BFL 0 CT 2 8 2DD5 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation SI Subsequent to operation 189 1499 4354 245 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Mike Mooney @ 263-4574 Mike Mooney 11/1.: 4~ Form 10-404 Revised 04/2004 Title Phone Wells Group Team Leader , Date /Y:2 1 ¡J ;; Preeared by Sharon AI/sue-Drake 263-4612 Signature ORIGINAL Submit Original Only ) 2A-10 Well Events Summary ) Date Summary 09/19/05 DRIFT TBG TO AVA NIPPLE WITH 2.79" GAUGE. SET F-COLLAR STOP @ 4144' RKB. PERFORATED TBG @ EST. 4136' RKB. SET POGLM, TOP @ 4105' WLM, 4123' RKB. IN PROGRESS. [GL V] 09/20/05 TESTED PACKOFF @ 4123' RKB, GOOD. SET SLIP STOP @ 4122' RKB. SET F COLLAR STOP @ 2721' RKB & BOTTOM PACKOFF @ 2718' RKB. ATTEMPTED PERFORATE TBG @2 711' RKB, NO SUCCESS. IN PROGRESS. [GLV] 09/21/05 PERFORATED TBG @ 2722' RKB W/ KINLEY PERFORATOR. SET K-3 PACKOFF & POGLM ASS'Y @ 2702' RKB. PRESSURE TEST PACKOFF 2000 PSI, GOOD. SET SLIP STOP @ 2701' RKB. [GL V] MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~3'~g'~ DATE: Commissioner THRU' Tom Maunder, ~ P. I. Supervisor January 4, 2001 FROM' Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit -2A Pad Thursday, January 4, 2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2A Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2A-12 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2A Pad in the Kuparuk River Field. KRU 2A Pad, 12 wells, 24 components, 1 failure 4.1% failure rate 21 wellhouse inspections Attachment: SVS KRU 2A Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation C'ommission Safety Valve System Test Report Operator: Phillips Submitted By: Chuck Scheve Date: 1/4/01 Operator Rep: Eamie Barndt Field/Unit/Pad' Kuparuk / KRU / 2A Pad AOGCC Rep: Chuck Scheve Separator psi: LPS 96 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, NUmber Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2A-01A 1840570 2A-02 1840500 2A-03 1840510 2A-04 1840530 ,, 2A-05 1840670 ~2A-06 1840640 ,, 2A-07 1840650 2A-08 1852480 2A-09 1860010 96 70 50 P P OIL ~A-10 1860020! 96 70 55 P P OIL ~A- 11 1860030 96 70 50 P P OIL 2A-12 1860040 96 70 70 P '"4 OIL 2A-13 1851440 96 70 50 P P OIL 2A-14 1851450 96 70 70 P P 0IL 2A- 15 1851460 96: 70 70 P P OIL 2A- 16 1851470 96 70 70 P P OIL 2A-17 1931400 96 70 50: P P OIL 2A- 18 1950590 96: 70 60! P P OIL -2A-19 1931520 " 2A-20 1931510 2A-21 1931330 , 2A-22 1950680 96 70 70! P P OIL! 2A-24 1931440 96 70 60 P P OIL ,, 2A-25 1960620 Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1% [] 9o Day Remarks: ,.Surface Safety on 2A-12 had slow leak, valve to be serviced and retested MICROFILMED 9/11/O0 DO NO-/' PLACE ANY NEW MATERIAL UNDER THIS PAGE 1. Type of Request: 2. Name of Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Plugging Pull tubing Alter casing ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4, Location of well at sudace Stimulate X Repair well 5. Type of Well: Development * Exploratory _ Stratigraphic _ Service _ Perforate Other 1326' FSL, 53' FEL, Sec. 14, T11N, R8E, UM, At top of productive interval 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UM At effective depth 1428' FNL, 1352' FEL, Sec. 23, T11N, R8E, UM At total depth 1487' FNL, 1388' FELr Sec. 23, .TllN, R8E, UM 12. Present well condition summary Total Depth: measured 7 2 6 0 feet true vertical 6247' feet 6. Datum elevation (DF or KB) 123' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-10 Permit number/approval number 86-~ 10. APl number 50-103-20056 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 7 1 5 0' feet true vertical 61 62 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 1 16' 1 6" 310 Sx CS II 106' 1 06' 2828' 9 5/8" 810SxAS III& 2863' 2773' 290 Sx Class G 6655' 7" 200SxClassG&175SxCSI 6690' 5799' 813' 5" 140 Sx Class G 6437'-7250 5597'-6239' measured . 6783'-6837' 6892'-6902' 6918'-6950' REEEIVED true vertical 5874'-591 7' 5961 '-5969' 5981 '-6006' Tubing (size, grade, and measured depth) NOV 2 8 1990 3-1/2" (199 jts), J-55 & 2-3/8" (13 jts) N-80, tbg w/tail @ 6884' Packers and SSSV (type and measured depth) Alaska 0il & Gas Cons. FHL pkr ~ 6300'r Baker DB ~ 6851'. Camco TRDP-1A-SSA SSSV ~ 1793'. Anch0raae' -- 13. Stimulation or cement squeeze summary Two attempts to hydraulically fracture stimulate the A Sand, screended out in 2ppg stage both times Intervals treated (measured) A Sand, 6918'-6950' Treatment description including volumes used and final pressure Placed a total of 4,200 lb of 16/20 ceramic.p.r.o, ppant. Final treating pressure = 7274 psi. 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 241 1 77 - 0 - 1 1 00 1 90 Subsequent to operation 592 506 0- 1400 225 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector m Oil LX Gas .... Suspended Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, In_. ¢) Subsidiary of Atlantic Richfield Company ELL ,NTRACTOR REMARKS PBDT WELL SERVICE REPORT JDAYS DATE F~'c,c ~,~,,~ ", o~/ ,,,,- u I d t I f~ - Toh, I - , - Tok~ 2 ,~0 0372 Al_ Ki,fr'lo6?, ~xL~KIVEL/ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ! Temp. I Chill Factor I Visibility Wind Vel. Report i *F ii *FI miles J Signed knots, REMARK~ · ~"i:~';~, " F'~AC "A" 8AND ~ q" ' L . . ' 1o05 1014 jZ,OO i. A4AX i_ i i i i II I REEEI'VED NasRa.0il ,& Gas Cons. Commission Anchorago CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK , ,,, knot81Stgned STATE OF ALASKA '~ ALASK~ OIL AND GAS CONSERVATION L,~'MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-2 3. Address 8. APl Number P. 0. Box 100360~ Anchorage~ AK 99510 50- 4. Location of well at surface 9. Unit or Lease Name 1327' FSL, 53' FEL, Sec. 14, TllN, R8E, UM KuDaruk River Unit At Top Producing Interval 10. Well Number 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UM 2A-10 At Total Depth 11. Field and Pool 1487' FNL~ 1:388' FEL, Sec. 23, TllN, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 12:3' RKB I ADL 25570 ALK ;~668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/30/86 02/06/86 02/08/86* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7260'MD~6247'TVD 7094'MD,6118'TVD YESx[~] NO [] 1803 feet MD 15On' 22. Type Electric or Other Logs Run D I L/SFL/SP/CNL/GR/FDC .CBL .GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" F;2;~ H-a_0 Surf !06' 24" 3!0 sx CS I! 9-5/8!! '~_0# .]-~ ~,_lrf 9R~I !2-!/~," 8!0 sx CS !!! & 3!0 sx (5 II 7" 26.0# .I-c,c, R~rf ~ql')' R-l/?' 91¥~ ~, ¢'1~ ~. ~. 1-/c, ~,, r,~ I 5" 18.0# L-80 6~7 ' 77~;0 ' 6-1/8" 140 sx C. 1 ass G 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 (MD) 6783'-6837'MD 5874'-5917'TVD w/12 spf, 120°phasing 3-1/2"/2-3/8" 688a.' 5319' & 5851' 6918'-6950'MD 5981'-6006 'TVD w/6 spf, 60° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ Fl'ow Tubing Casing Pressure CALCULATED.1~ 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. NONE Form 10-407 * NOTE: Tubing was run and the CONTINUED ~)a~dE~ ~bE Rev. 7-1-80 well erfor 8 (DAM) WC1/107 Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 6731' 6842' 6872' 7036' TRUE VERT. DEPTH 5832' 5922 ' ~94.5' 6073' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NA 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer °ate INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing 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 10407 STATE OF ALASKA ALASKA r~lL AND GAS CONSERVATION CO,¢iMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED E~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number AR60 Alaska, Inc. 86-2 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20056 4. Location of well at surface 9. Unit or Lease Name 1327' FSL, 53' FEL, Sec.14, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2A-10 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 123' RKB ADL 25570 ALK 2668 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 01/30/86 02/06/86 02/08/86 N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7260 'MD 7150 'MD YES [] NOI N/A feet MD 1500' (approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/CNL/GR/FDC 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 106' 24" 310 sx CS II 9-5/8" 36.0# J-55 Surf 2863' 12-1/4" 810 sx CS Ill & 310 sx CS II 7" 26.0# J-55 Surf 6690' 8-1/2" 200 sx Class G & 175 sx CS I 5" 18.0# L-80 6437' 7250' 6-1/8" 140 sx Class G 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 (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 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.1~ 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. None RECEIVED APR 0 4 1986 Anchorage Form 10-407 DAM2/WC02 Rev. 7-1 ~80 CONTINUED ON REVERSE SIDE Submit in duplicate / 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 3!. LIST OF ATTACHMENTS We]] History, Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing 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 SUB-~URFACE DIREC3'IONAI. SURVEY I~UIDANCE I~[ONTINUOUS I~OOL Company Well Name Field/Location ARCO ALASKA, INCORPORATED WELL 2A-10 (1326'FSL, 53'FEL, S14, TllN, R8E) KUPARUK, NORTH SLOPE, ALASKA Jol3 Reference NO. 71416 Loaaed 8y..' ~ARSA Date, Computed BOLAM GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARC~ ALASKA9 INC. 2A-lO KUPARUK NORTH SLOPEgALASKA SURVEY DATE: 20 MAR 86 ENGINEER: O. BARBA METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL. AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH.2$ DEG 35 MIN WEST COMPUTATION DATE: 17-APR-86 PAGE ARCO ALASKA~ INC. 2A-10 KUPARUK NORTH SLOPEtALASKA TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN DATE OF SURVEY: 20 MAR 86 KELLY BUSHING ELEVATION: ENGINEER: O. BARBA 123.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR.COORDINATES H3RIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIRUTH FEET DEG/IO0 FEET FEET FEET DEG MIN o.ooo.oo -~z~.oo o o. o o ~o.ooo.oo o.oo . o.oo e ~oo.oo ~oo.oo -~.oo o ~o , ~ ~ ,o.~ ~.~s o.o~ , o.~ , zoo.oD zoo.oD ~.ooo ~, 6~ ~ .' o.o~o.~l o.~6 , ~.ol . ~oo.oo z~.~~.~ o ~, ~ ~ .o.~ o.~ 0.6, , ~.~ . ~oo.oo ~.~.~.~ o ~, ~ ,~ . o.~so.o~ o.,~ , ~.~ , 0 ,4 S 8, 41 W 2.02 0.24 Z.67 N 10.25 W 0 27 N 67 51 W 2.39 0.40 2.77 N 11.32 W S 73 I W 2.60 0.27 2.80 N 11.88 W N 79 51 W 3.02 0.28 2.69 N 12.63 W S 66 48 W 3.06 0.63 Z.88 N 13.10 W S 31 47 W 3,44 0,44 2.54 N 13.27 W S ,0 21 W 5.16 3.90 1.18 N 1&.SZ W S 37 53 W 12.36 ,.18 4.57 S 19.09 W S 30 59 W 25.94 3.92 15.94 S 26.78 W S 31 19 W 44.58 0.22 31.96 $ 36.¢8 W 1000.00 999.94 876.94 1100.00 1099.93 976.93 1200.00 1199-93 1076.93 0 Z4 1300.00 1299.92 1176,92 0 28 1,00.00 1399.92 1276.92 0 5 1500.00 1499.92 1376.92 0 22 1600.00 1599.90 1476.90 2 27 1700.00 1699.60 1576.60 6 2 1800.00 1798.64 1675.64 9 49 1900.00 1896.87 1773.87 10 56 S 27 3 W 64.84 3.71 S ZO 25 W 90.60 4.05 S 13 30 W 120.50 2.71 S 18 4 W 154.44 S 24 40 W 192.26 3.91 S 26 57 W 234.08 3.46 S 23 30 W 280.95 3.57 S 20 ,3 W 331.34 2.77 S 20 42 W 385.60 2-80 S 20 38 W 443.41 0.81 2000.00 1994.78 1871.78 13 9 2100.00 2091.37 1968.37 16 31 ZZO0.O0 2186.62 2063.62 18 55 2300.00 2280'51 2157.51 21 18 2400.00 2373.00 2250.00 23 23 2500.00 2463.81 2340.81 26 ZO i~! O0 2552.13 2,29.13 29 1, ,00. 2638.,1 2515.41 31 38 28 0.00 2722.25 2599.25 34 26 2900.00 2803.71 2680.71 36 I S 20 59 W 502.30 1.95 S 23 39 W 562.57 0.43 S 23 31 W 622.96 0.19 S 23 29 W 683.31 0.26 S 23 25 W 743.93 0,10 S 23 12 W 804.71 0.18 S 23 5 W 865.58 0.20 S 23 4 W 926.35 0.26 S 23 O W 986.82 0.34 S 22 58 W 1046.90 0.23 3000.00 2884.36 2761.36 36 34 3100.00 2964.08 2841.08 37 Z2 49.64 S 73.14 S 102.,7 S 135,46 S 46.48 W O. O0 N 0 0 E 0.31 ~ 84 26 4. 1.11 N 65 26 W Z. 09 N' 71 4 W 3.31 N 77 30 W 4.84 N 79 41 #' 6.20 N 77 24 W 7.44 N 76 5 W 8.57 N 74. 32 W 9.50 N 73 41 ~ 10.59 N 75 23 W 11.65 N 76 13 W 12.21 N 76 44 W 12.91 N 77 57 13.41 N 77 35 W 13.51 N 79 10 W 14.47 N 85 18 W 19.63 S 76 32 31.16 S 59 14 W 48.50 S 48 46 W 68.00 S 43 6 W 57.04 W 92.75 S 37 56 3: 65.03 W 121.36 S 32 23 W 74.70 W 154.69 S 28 52 W 170.92 S 88.23 W 192.34 S 27 18 W 208.21 S 107.18 W Z34.18 $ 27 14 B' 250.51 S 127.36 W 281.03 S 26 56 W 297,55 S 145.81 W 331.35 S 26 6 W 348.55 S 164.94 W 385.61 S 25 19 W 402.74 S 185.62 ~ 443.45 S 24 44 W ¢58.10 S 206.34 W 502.43 S 24 14 W 513.84 S 229.51 W 562.77 S Z4 4 W 3200.00 3043.77 2920.77 37 6 3300.00 3123.47 3000.47 37 16 3400°00 3202.96 3079.96 37 22 3500.00 3282.34 3159.34 37 30 3600.00 3361.54 3238.64 37 32 3700.00 3441-32 3318.02 37 21 3800.00 3520.51 3397.61 37 6 3900.00' 3600.51 3477.5! 36 51 569.20 S 253.72 W 623.19 S Z~ 1 W 624.59 S 277.81 W 683.58 S 23 58 #~'. 680.24 S 301.94 W 744.24 S 23 56 W 736.09 $ 326.02 W 805.06 S 23 53 W 792.13 S 349.95 W 865.99 S 23 50 W 848.08 S 373.80 W 926.81 S 23 47 903.77 S 397.50 W 987.33 S 23 44 W 959.15' S 420'98 W 1047.47 S 23 41 W ARCO ALASKAt INC. ZA-IO KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 17-APR-SA PAGE 2 DATE OF SURVEY: 20 MAR 86 KELLY BUSHING ELEVATION: 123.00 FT ENGINEER: D. BARBA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SD'B-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DZST- AZIMUTH FEET OEG/IO0 FEET FEET FEET' DEG MIN 4000.00 36g0.63 3557.63 36 38 S Z2 58 W 1106.67 4100.00 3760.B1 3637.81 37 13 S 23 12 W 1166.37 4200.00 3839.60 3716.60 38 21 S 23 40 W 1227.91 4300.00 3918.01 3795o01 38 19 $ 23 46 W 1289.94 4400.00 3996.46 3873.46 38 19 S 23 50 W 1351.91 4500.00 4075.02 3952.02 38 5 S 24 3 W 1413.76 7( ,00 ¢153.91 4030.91 37 43 S 24 15 W 1475 20 o00 4233.20 4110.20 37 26 S 24 24 W 1536.12 4800.00 4312.$7 4189.67 37 24 S 24 13 W 1596.81 4900.00 ¢392,05 4269°05 37 26 S 24 12 W 1657.60 5000.00 4471.48 4348,48 37 39 5100.00 4550.57 4427.57 37 33 5200.00 4629.55 ~506.65 38 8 5300.00 ~708.32 4585.32 37 56 5400.00 4787.31 4664.31 37 43 5500.00 4866.63 4743,43 37 44 5600.00 4945.20 4822.20 38 38 5700.00 5022.74 4899.74 39 22 5800.00 5099.87 4976.87 39 33 5900.00 5177.09 5054.09 39 16 S 24~,55 W 1718.35 S 26 10 W 1779.54 S 26 16 W 1840.74 S 26 51 W 1902.46 S 27 14 W 1963.76 S 27 27 W 2024.88 S 27 O N 2086.46 S 26 47 W 2149.59 S 26 46 W 2213.22 S 25 ~4 W 2276.74 6000.00 5254.81 5131.81 38 37 6100.00 5333.11 5210.11 38 23 6200.00: 5411.50 5288.60 38 7 6300.00 5489.86 5366.86 38 6400.00 5568.03 5445.03 38 25 6500.00 5646.70 5523.70 37 42 O0 $806.$6 5683.66 36 68 .00 5887.64 5764.64 35 53 6900.00 5967.31 5844.31 38 21 S 26 35 W 2339.66 S 26 32 W 2401.84 S 26 13 W 2463-81 S 25 5 W 2526.06 S 24 ~9 W 2588.41 S 24 37 W 2650.15 S 24 34 W 2710.74 S 25 43 W 2770.17 S 31 27 W 2828.68 S 31 58 W 2888,73 7000.00. 6045.34 5922.34 39 0 7100.00 6122.99 5999.99 39 3 7200,00 6200.$3 6077.63 39 3 7260.00 6247.22 6124.22 39 3 S 31 8 W 2950.94 S 31 7 W 3013.66 S 31 7 W 3076.38 S 31 7 W 3114.01 0.26 1.96 0.13 0.08 0.17 0.34 0.45 0.33 0.28 0.21 1014.25 S 444,31 W 1107.29 S 23 39 N 1069.23 S ~67,71 W 1167.05 S 23 37 W 1125,71 S 492.25 W 1228,63 S 23 37 W 1182,52 S 517,22 W 1290,69 S 23 37 W 1239,25 S 542,25 W 1352.70 $ 23 37 ~ 1295.81 S 567.34 W 1414,57 S 23 38 W 1351.88 S 592.~9 W 1~76.02 S 23 39 W 1407.40 S 617.63 W 1536.96 S 23 41 W 1462.70 S 642.65 W' 1597.65 S 23 43 W 1518,18 S 667.55 W 1658.46 S 23 44 W 1.68 0.37 0.3¢ 0'3? 0.25 0,22 1-67 0.21 0.19 0.27 1573.52 S 692,62 W 1719.22 $ 23 45 W 1628.65 S 719.17 W 1780.37 S 23 49 W 1683.54 S 746,26 W 1841.52 S 23 54 W 1738.75 S 773.88 W 1903.19 S 23 59 W 1793,37 S 801.75 W 1964.43 S 24 5 W 1847.66 S 829.89 W12025.48 S 2~ 11 W 1902,41 $ 858.14 ~ 2087°00 S 2½ 16 E' 1958,76 S 886..65 W 2150.09 S 24 21 W 2015,56 S 915,35 W 2213,67 S 26 25 ~ 2072.25 S 944,04 N 2277.15 S 24 29 W' 0.60 2128.42 S 972.40 W 2340,03 S 24 33 W O.2T 2184.04 S 1000.24 W 2402.19 S 24 36 W 0,63 2239,52 S 1027.84 W 2464.13 S 2~ 39 W 0.60 2295.65 $ 1054.77'W 2526.37 S 24 40 W 0.42 2352.17 S 1081.13 W 2588.73 S 24 41 W 0.99 2408.26 S 1106.93 W 2650.47 S 2~:41 W' 0,89 2463.33 S 1132.21 W 2711,07 S 2~ ~1 W 3,94 2517,35 S 1157,01 W 2770,51 $ 2~ 41 W 1.60. 2568.57 S 1185.54 W 2828.96 S 24 46 ~' 1'06 2619.87 S 1217.45 W 2888.92 S 24 55 W: 0,50 2673,19 S 1250,13 W 2951-06 S 25 3 W 0,00: 2727.13 S 1282,69 W 3013,73 S 25 11 W 0,00 2781.08 S 1315,26 W 3076,41 S 25 18 ~ 0.00 2813,45 S 1334.80 W 3114.03 S 25 22 W ~RCO ALASKA, INC. CUPARUK tORTH SLOPE, AL 6S:'(.A COMPUTATION DATE: 17-APR-DS TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN PAGE 3 DATE OF SURVEY: 20 MAR 86 KELLY BUSHING ELEVATION: 123.00 FT ENGINEER: D. BARBA INTERPOLATED VALUES FOR EVEN [000 FEET gF MEASURED DEPT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH O.OO 0.00 -123.00 0 0 ,000.00 999.9, 876.9, 0 44 ~000.00 1994.78 1871.78 13 9 3000.00 2884.36 2761.36 3634 ,000.00 3680.,3 3557.63 36 38 5000.00 ,471.,8 ¢348.,8 37 39 $00' O0 5254.81 5131.81 3837 ? 60 O0 6045.34 5922.34 39 0 ~26U.00 6247.22 612,.Z2 39 3 FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 27 3 W 64.84 S 20 59 W 502.30 S 22 58 W 1106.67 S 2,:55 W k718.35 S Z6 35 W Z339.66 S 31 8 W 2950.94, S 31 7 W 3114.01 0.00 3.71 1.95 0.26 1.68 0.60 0.50 0.00 0.00 N 0.00 E 0.00 N 0 0 E 2.67 N 10.25 W 10.59 N 75 23 W 49.64 S 46.48 W 68.00 S 43 6 W ¢58.10 S 206.34 W 502.4.3 S 24 14. W 1014.25 S 444.31 W 1107.29 S 23 39 N 1573.52 S 692.62 W 1719.22 S 23 45 W 2128.42 S 972.40 W 2340.03 S 2~ 33 W 2673.19 S 1250.13 W 295t.06 S 25 3 W 2813.4,5 S 133¢.80 W 311~.03 S 25 22 W: ~2CD ALASKA, INC. 2~-10 KUPARUK HORTH SLOPE~ALASKA COMPUTATIDN DATE: 17-APR-86 PAGE 4 DATE OF SURVEY: 20 MAR 86 KELLY BUSHING ELEVATION: 123,00 FT ENGINEER: D. BARBA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE E&SURED VERTICAL VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -123.00 0 0 N 0 0 E 23.00 23,00 -100.00 0 11 N 43 54 W 123.00 123.00 0.00 0 24 N 57 52 W 223.01 223.00 100.00 0 33 N 68 48 W 323.01 323,00 200.00 0 39 N 88 9 ~ ¢2~.02 423.00 300.00 0 47 N 87 53 W 5~ 03 523.00 400.00 0 47 N 68 19 W ,04 623.00 500.00 0 40 N 69 6 W 723.05 723.00 600.00 0 39 N 64 55 W 823.06 823.00 700.00 0 36 N 57 58 W 923.06 923,30 800,00 1023,07 1023.00 900.00 1123.07 1123.00 1000.00 1223.07 1223.00 1100.00 1323.08 1323.00 1200.00 1423.08 1423.00 1300.00 1523,08 1523.00 1400.00 1623.13 1623.00 1500.00 VERTICAL DOGLEG RECTANGULAR COORDINATES H3RIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET. DEG MIN 0.00 0.00 0.00 N 0.00 E 0.01 0.94 0.00 N 0,04 W 0.10 0.39 0.10 N 0.44 W 0,03 0.09 0.55 N 1.21 W 0.35 0.18 0.69 N 2.24 W 0.87 0.13 0.73 N 3.55 W 1.31 0.82 0.98 N 5.10 W 1.44 0.70 1.44 N 6.33 W 1.52 0.39 1.89 N 7.45 W 1.49 0.71 2.42 N 8.49 W 0 34 N 85 15 W 1.59 0 41 S 82 39 W' 2.17 0 Z1 N 68 23 W 2.39 0 2:3 S 72 9 W 2.71 0 25 N 72 20 W 3.06 0 9 S 30 22 W 3. l l 0 27 S 36 25 W 3.61 3 20 S 39 37 W 6.30 S 36 8 W 14.99 S 30 53 W 30.37 1723.55 1723o00 1600.00 6 56 1824.76 1823.00 1700.00 10 33 S 30 39 W 49.61 S 25 35 W 71.72 S 16 46 w 100,16 S 15 53 w 133.00 S ~20 23 W 171.28 S 27 9 w 214.60 S 25 2 W 264.85 S 20 47 W 321.95 S 20 43 W 386.11. S 20 31 W 457.43 1926.61 1923.00 1800.00 11 13 2029.05 2023.00 1900.00 14 12 Z133.06 2123.00 2000.00 17 19 2238.55 2223.00 2100.00 19 45 2345.76 2323.00 2200.00 22 14 2454.77 2423.00 2300-00 24 53 256~ 71 2523.00 2400.00 28 25 26 94 2623.00 2500.00 31 9 2800.90 2723.00 2600.00 34 28 2923.88 2823.00 2700.00 36 9 3048.30 2923.00 2800.00 37 9 3173-95 3023.00 2900.00 37 6 3299.41 3123.00 3000.00 37 16 3425.21 3223.00 3100,00 37 25 3551.26 3323.00 3200-00 37 32 3577.33 3423.00 3300.00 3T 24 3802.99 3523.00 3~00.00 3T 6 3928.10 3623.00 3500.'00 36 ~7 ~052.76 3723.00 3600.00 36 36 6178.84 3823.00 3700.00 38 17 S 22 36 W 531.21 S 23 32 W 607.24 S 23 29 W 682.96 S 23 2~ W 759.22 S 23 6 W 835.90 S 23 5 W 912.60 S 22 59 W 988.62 S 22 57 W 1063.72 S 23 3 W 1138o08 S' 23 37 W 1214.79 0.62 2.70 N 9.34 W 0.49 2.54 N 10.54 ~ 0'75 2.84 N 11.48 W 0.19 2.75 N 12.04 W 0.39 2.74 N 12,80 W 0.23 2.84 N 13.13 W 0.32 2.40 N 13.37 W 3.58 0.28 N 15.18 W 3.65 6.71 S 20.70 W 2.03 19.76 S 29.06 W 1.65 3.90 4.26 3.40 3.47 3.22 3.Z7 2.77 2.80 0.43' 2.31~ 0.22, 0.26 0.38 0.12 0.27 0.33 0.22 0.38 0,.40 O. O0 N 0 0 E 0.04 N 88 10 W 0.45 N 77 24 W 1.33 N' 65 43 W 2.35 N 72 53 W 3.62 N 78 24 W 5.19 N 79 5 W 6.:49 N"77 11 W' 7.69 N 75 47 W 8.83 N 74 7 W 9.72 N 73 51 W 10.87 N' 75 57 11.82 N 76 6 W 12.35 N 77 7 13.09 N 77 56 W 13.43 N'T7 47 W 13.58 N 79 49 W 15.18 N 88 56 W 21.76 S 72 2 W 35.14 5'55 47 36.28 S 39.10 W 53.34 S 47 8 W 55.81 S 49.52 W 74.61 S 41 34 W 82.24 S 60.16 W 101.90 S 36 10 W 114.79 S 68.22 W 133.53 151.53 S 80.16 W 171.42 S 27 52 W 190.90 S 98.22 W 214.69 S 27 13 W 235.86 S 120.70 W 264.95 S 27 6 W 288.74 S 142,46 W 321.9T S 26 15 349.02 S 165.11 W 386.11 S 25 19 W' 415.91 S 190.57 W ~57o49 $ 24 36 W 485.0.3 S 217.07 W 531.39 S 24 6 W 554.78 S 247.44 W 607.46 S 2~ 2 W ' 624.26 S 277.66 W 683.22 S 23 58 W 694.28 S 308.02 W 759.54 S 23 55 W 764.80 S 338.30 W 836.28 S 23 51 W 835-42 S 368-40 N 913.04 5 23 47 W: 905.43 S 398.21 W 989.13 S 23 44 W 974.65 S 427.55 W 1064.31 S 23 41 W 1043.19 S 456.59 W 1138.73 S 23 38 W 1113.69 S 486.98 W 1215.50 S 23 37 W COMPUTATION DATE: 17-APR-86 PAGE 5 ARCO ALASKA, INC. 2A-lO KUPARUK NORTH SLOPE~ALASKA DATE OF SURVEY: 20 MAR 86 KELLY BUSHING ELEVATION: ENGINEER: D. BARBA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 123.00 FT TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HgRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET. DEG MIN ,306.36 3923.00 3800.00 38 19 ,,33.82 ,023.00 3900.00 38 15 · 560.88 ,123.00 ,000.00 37 ,687.15 4223.00 ,100.00 37 27 ,813.01 ,323.00 ,200.00 37 25 ,93'.97 ,,23.00 ,300.00 37 ZO 51'50i. 20 ,523.00 4400.00 37 _.55 ,623.00 4500.00 38 oo.oo S 23 ,7 W 1293.88 S 23 53 W 1372.87 S 2, 11 W 1¢$1.22 S 2, 2, W 1528.30 S Z, 12 W 1604.71 S 2, 15 W 1681.27 S 25 56 W 1758.31 S 26 15 W 1835.52 S 26 55 W 1913.89 S 27 23 W 1991'33 0.07 0.29 0.22 0.28 0.35 0.72 0.55 0.32 0.27 1186.13 S 518.81 W 129,.63 S 23 37 W' 1258.¢3 S 550.73 W 1373.66 S' 23 38 W 1330.01 S 582.65 W 1,52.0, S 23 39 W 1,00.27 S 614.,0 W 1529.13 S 23 41 W 1,69.91 S 645.89 W 1605.56 S 23 ,3 W 1539.77 S 677.26 W 1682.1, S 23 ¢, W 1609.59 S 709.8, W 1759.161 S 23 47 1678.86 S 743.95 W 1836.31 S 23 53 W 1748.95 S 779.05 W 1914.61 S 2, 0 W 1817.87 S 814.,0 W 1991.96 S 2, 7 W. 5571.66 ,923.00 4800.00 38 13 5700.33 5023.00 ,900.00 39 22 5829.99 5123.00 5000.00 39 31 5959.20 5223.00 5100.00 38 56 6087.09 5323.00 5200.00 38 24 621,.,9 5423.00 5300.00 38 7 63,2.,6 5523.00 5400.00 38 36 6,69.97 5623.00 5500.00 38 2 6595.96 5723.00 5600.00 36 ,6 6720.2, 5aZ3.00 5700.00 36 5 68,3.88 5923.00 5800.00 37 5 6971.25 6023.00 5900.00 38 56 7100.01 6123.00 6000.00 39 3 7228.80 62Z3.00 6100.00 39 3 7260.00 6247.22 612,.22 39 3 S 27 10 W 2068.85 S 26 47 W 21,9.80 S 26 ,7 W 2232.31 S 26 ,7 W 2314.11 S 26 3, W 2393.82 S 26 6 W 2472.75 S 25 3 W 2552.60 S 24 38 W 2631.70 S 2, 33 W 2708.32 S 27 10 W 2782.10 S 31 51 W 285~.52 S 31 17 W 2932.95 S 31 7 Wi 3013.67 S 31 7 W 3094.45 S 31 7 W 311~.01 1.60 0.22 0.17 0.97 0.25 0.98 0.53 0.78 2.94 0.38 0.00 0.00 0.00 1886.73 S 850.12 W 2069.&1 S 1958.94 S 886.75 W 2150.30 S 2, 21 W Z032.61 S 923.9, W 2232o75 S 2, 26 W 2105.59 S 960.93 W 2314.50 S 2~ 31 W 2176.86 S 996.66 W: 2394.17 S 2, 36 W 2247.55 $ 1031.80 W 2,73.07 S 2319.69 S 1066.02 W 2552.91 S 2, ,0 W 2391.49 S 1099.24 W 2632.02 S 2~ 41 W 2~61.13 S 1131.21 W 2708.66 $ 2528.05 S 1162.29 W 2782.,½ S 2, 41 W 2590.66 S 1199.22 W 285,.76 S Z~ 50 W 2657.73 S 12,0.76 W 2933.09 S 25 1 W 2727.1, S 1282.70 W 3013.7, $ 25 11 W 2796.62 S 132,o6, W 309,.~7 S 25 20 W 2813.,5 S 1334.80 W 3114.03 S 25 22 W ARCO ALASKAt INC. 2A-IO KUPARUK NORTH SLOPE~ALASKA MARKER TOP RUPARUK C BASE KUPARUK C TOP KUPARUK ~ BaSE KUPARUK A COMPUTATION DATE: 17-APR-B5 PAGE 6 DATE OF SURVEY: ZO MAR 86 KELLY BUSHING ELEVATION: 123.00 FT ENGINEER: O. BARBA INTERPOL&TED VALUES FOR CHOSEN HORIZDNS SURFACE LOCATION AT ORIGIN= 1326' FSL~ 53' FEL~ SEC 14~ TI1N~ RBE~ RECTANGULAR COORDINATES ~EASURED DEPTH TVD BELOW KB FROM KB SUB-SEA NORTH/SDUT~ EAST/WEST 6731.00 5831.69 5708.69 2533.67 S 1165.25 6842.00 5921.50 5798.50 2589.70 S 1198.62 W 6872.00 5945.31 5822.31 2605.20 S 1208.26 W 7036.00 6073,30 5950.30 2692.60 S 1261.85 W 7150.00 6161.81 6038.B1 2754.11 S 1298.97 W' 7Z60.00 6247.22 6126.Z2 Z813.~5 S 133¢.B0 W ~M COMPUTATION DATE: [7-APR-86 PAGE ? ARCO ALASKA~ INC. DATE OF SURVEY: 201MAR 86 2A-10 KUPARUK N3RTH SLOPEsALASKA KELLY BUSHING ELEVATION: ENGINEER: D. BARBA 123.00 FT ~~~ STRATIGRAPHIC SUMMARY MARKER MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGIN= 1326' FSL, 53' FEL, SEC. 1~, TX1N, RSE, UM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTh' EAST/WEST TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 6731.00 6842.00 6872.00 7036.00 7150.00 7260.00 5831.69 5708.69 2533.67 S 1165.15 W 5921.50 5798.50 2589.70 S 1198.62 W 59~5.31 5822.31 2605.20 S 1208.26 W 6073.30 5950.30 2692.60 S 1261.85 W 6161.81 6038.81 275,~. 11 S 1298.97 6247.22 612~,. 22 2813./,5 S 133~.80, FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASU'RED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET, 3EG MIN 7260.00 52~7.22 ~124.22 311~.03 S 25 21 W SCHLUMBEROER El ;[ RECT i ONAL SURVFY COMPANY ARCO ALASKA iNC. NELL 2A- 10 FiELO KUPAP, UK COUNTRY USA RUN ONE OATE LOGGED 20 - MAP - 96 REFERENCE 0000714~6 WELL 2A- 10 (1326'FSL, 53'I S14, TllN, R8E) H£ ,ONTAL PROJECTION NO~?H ~000 REF 0000714]S soo -5O0 -~000 -lSO0 -2000 -2500 i .... : ' ~' ":; .... t ~ ': ~ ..... ~'' ' : ! ' I ' ...... ": .... i ...... "! · ~," i , ,i' "1,"., SOUTH -30001 -g500 -gO00 - ! SO0 - ! 000 -500 WEST WELL '2A-10 (1326'FSL, 53'FE $14, TllN, R8E) VERTICAL PROJECTION PROJECTION ON VEF~T!CAL PLANE 205. - gS. SCALED Ie,~ 'vEF~T!C~L C]EP'~H6' H'DRIZ SC.qLS' : l/lO00 IN,.,F'r STATE OFALASKA -' 0 R I G i N A L AL~,.,/~, OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1326' FSL, 53' FEL, Sec. 14, T11N, R8E, UM At top of productive interval 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UM At effective depth 1428' FNL, 1352' FEL, Sec.23, T11N, R8E, UM At total depth 1487' FNL, 1388' FEL, Sec. 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7 2 6 0' true vertical 6 24 7' Effective depth: measured 71 5 0' true vertical 61 6 2 Casing Length Size Structural Conductor I 1 6' 1 6" Surface 2 8 2 8' 9 5/8" Intermediate feet Plugs (measured) feet Nolle feet Junk (measured) feet None Cemented 310 Sx CS II 810 Sx CS III & 290 Sx CS II 6. Datum elevation (DF or KB) RKB 123 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2A-10 9. Permit number 86-2 10. APl number 5o-1 03-20056 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 106' 106' 2863' 2773' Production 6 6 5 5' 7" Liner 8 1 3' 5" Perforation depth: measured 6783'-6837', true vertical 5874'-5917', 200SxClassG&175SxCSI 6690' 5799' 140 Sx Class G 6437'-7250' 5597'-6239', 6197' 6892'-6902', 6918'-6950' 5961'-5969', 5981'-6006' Tubing (size, grade, and measured depth) 3 1./2" (199 jts), J-55 & 2 3/8" (13 its) N-80, tbg w/tail @ 6884' Packers and SSSV (type and measured depth) FHL Pkr @ 6300', Baker DB @ 6851', Camco TRDP-1A-SSA SSSV @ 1793' Attachments Description summary of proposal ~ Detailed operation program 13. Refrac A. Sands with 16,500 lbs Carbo-Lite proppant (Wellbore Schematic attached). 14. Estimated date for commencing operation [15. Status of well classification as: ~ Se.Dtember, 1990 I Oil ~ Gas _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I he~~,~thefore~,oingistrueandcorrecttothebestofmyknowledge.~~,.~__~._~ ? /q Si~lned · - -"-,- Title Senior Operations Engineer Date '" FOR COMMISSION USE ONLY BOP sketch Suspended Conditions o! approval: Notify Commission so representative may witness Plug ihtegrity __ BOP Test Mechanical Integrity Test_ A~?roved b~f or(~er .of the Commission Location clearance Subsequent form require ORIGINAL SI6NED BY LONNIE C. SMITH 10- Z/,_~Zt Commissioner Form 10-403 Rev 09/12/90 Approve~l Copy R~turrted ,_ ?o IApproval_No. SUBMIT IN TRIPLICATE · e Attachment 3 Kuparuk Well 2A-10 'A' Sand Re-Fracture Cost Tracking AFE #K81069 RU fracture equipment. Install "Tree Saver". Pressure up the 7" annulus to 3000 psi. Note: AAI Drilling Reported on 3/28/86 that they could not get Dowell's tree saver to set. Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled water with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. Pump the 100 Bbl pre-pad at 20 BPM. Shut down and determine the ISIP. pressures following the ISIP. WHTPE = Fracture Gradient = Frac Fluid Gradient = Tubing Friction = Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute Expected wellhead treating pressure: 3,540 psig 0.71 psi/ft (5960' TVD) 0.44 psi/ft 263 psi/1000' @ 20 BPM (3-1/2") 600 psi/1000' @ 20 BPM (2-3/8") * If excessive treating pressures are experienced, reduce the rate in small increments, as often as necessary, adjusting additive rates as appropriate. With diesel on the backside, the maximum recommended treating pressure is 6500 psi based on analysis of tubing strength between the packers. Operations Engineer -- Obtain representative fluid samples from the pad, slurry, and flush stages. Place samples in hot water bath at 150° F to observe break time. 5. Rig down fracture stimulation equipment. KUPARUK WELL 2A-10 'A' SAND FRACTURE PUMP SCHEDULE Max Allowable Treating Pressure = 6,500 psi SI'AGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME DESCRIPTION BBI.S BI=M PPG DESCRIPTION LBS STG/CUM 9/4/90 HIT PERFS CUM Bi3LS 1 GW PRE-PAD 100 20 0 - - 0 100 / 100 .............................................. SHUT DOWN FOR ISIP .................................................. 2 GWPAD 128 20 0 - - 0 128/ 228 3 GW wi2 PPG 7 20 2 12/18 M CARBO-LFrE 588 8 / 236 4 GW wi4 PPG 8 20 4 12/18 M CARBO-LITE 1,344 9 / 245 5 GW w/6 PPG 8 20 6 12/18 M CARBO-LITE 2,016 1 0 / 255 6 GW w/7 PPG 9 20 7 12/18 M CARBO-LITE 2,646 I 2 / 267 7 GW w/8 PPG 9 20 8 12/18 M CARBO-LITE 3,024 1 2 / 279 8 GW w/10 PPG 8 20 1 0 12/18 M CARBO-LITE 3,360 I 2 / 291 9 GW w112 PPG 7 20 1 2 12/18 M CARBO-LrrE 3,528 I I / 302 I 0 SLICK DIESEL FLUSH 56 +SV 20 0 - - 0 56/358 58 158 286 294 303 313 '325 337 349 NIA Total Gelled Water (less diesel in stages 1-4) = TOtal Gelled Diesel (Stages 1 thru 4 and 10) = NOTES: 272 BBLS'+° SV and Tank Bottoms 68 16,506 Shut down for a minimum of 20 minutes between stages 1 and 2 to minimize height growth. Crosslinker should be cut to zero for last 56 bbls of Stage 1 Stages I and 2 are Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. Stages 3 through 9 are Gelled Water with 6 hour breaker and WITHOUT silica flour. Stages 1 through 4 will also contain 5*/. Arctic Diesel by volume for additional fluid loss control. Stage 10 is a gelled diesel flush, and it should include a volume adjustment for surface equipment between the wellhead and densitometer. This job is intentionally underflushed blt 2 bbls. The blender tub should be bypassed at flush. All fluids should be maintained at 100' F on the surface. KUPARUK WELL 2A-10 APl ti:. ~lg~OQ6~QO ~PUO OATE: 01,~01~ PERMIT ~. WORKOVER DATE: ORIQ~ RKB: k 88.2 UNER DETAII.~ SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE IO OEPTH AVA AVA '8PL.' NIPPLE ~ CAMCO 'O 1.812' MM SHROUT CAMCO 6873 INTERVAL 67~I. M37 6918-6050 PERFORATION DATA ZONE FT ~=F PHASE C234 54 1~ 12o M 32 $ 60 C~MM~N SOS 3 3~" SOS 3 3~ 14180. DATA DEPTH DATE: 01/17/89 IJPOATE ARCO Alaska, In Post Office =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5936 RETURN TO: ARCO Alaska, Inc. -Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledgereceipt and return one signed copy of this.transmittal. ,~ 2A-12 3F-16 2A-10 3N-4 3N-3 3Q-7 3Q-6 3Q-2 3N-5 2T-17 2T-13 2T-10 CET. 3-8-86 6410-7007 CET 1-13-86 7740-8443 CBL 3-20-86 6500-7042 CET 3-25-86 6690-7736 CET 3-25-86 6587-8016 CBL 2-15-87 6698-8908 CBL 2-14-87 7494-9545 CBL '2-15-87 7843-9752 CBL 2-15-87 7809-9941 CET 3-25-86 5590-7456 CET 9-5-86 6947-8236 CET 9-1-86 6900-7752 CET 9-4-86 4700-8118 'Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCornpany .... STATE OF ALASKA .... ALASt OIL AND GAS CONSERVATION COMIt 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate)(] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 123 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, Alaska 99510 Kuparuk River Unit 4. cation of well at surface 386r FSL, 53' FEL, Sec. 14, TllN, R8E, UM At top of productive interval 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UN At effective depth 1428' FNL, 1428'.FNL, 1352' FEL, Sec. 23, T11N, 48E, UN ~tt4~al (~_~h, 1388' F~L, Sec, 23, T11N, R8E, UM 7. Well number 2A-10 8. A~r_o~al number 50-- - 200576 10. P~paruk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 7260 None 6247 feet Plugs (measured) . feet 7150 Effective depth: measured 6162 feet true vertical feet Junk (measured) None Casing Length Size Cemented Measured depth Conductor 106' 16" 310 SX CS 11 106' Surface 2828' 9-5/8" 810 sxCSIII 2863' & 290 sxCSII ProductiQn 6655' 7" 200 sx Class G 6690' & 175 sxCS1 Liner 813' 5" 140 sx Class G 6437'-7250' ~ue Vertical depth 106' 2773' 5799' 5597'-6239' Perforation depth: measured 6783'-6837' 6918'-6950' 6892'-6902' MD (New Perfs) true vertical 5874'-5917' 5981'-6006' 5961'-5969' TVD (New Perfs) ~bing(siz~ grade,,an.dmeasure¢ dept~ 3-1/2 (199 jts}, J-55 & 2-3/8" (13 jts) J-55, tbg w/tail @ 6884' Packers and SSSV (type and measured depth) FHL pkr @ 6310', DB pkr @ 6861' & TRDP-1A-SSA SSSV @ 1803' 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) 6892'-6902' Treatment descriPtion including volumes used and final pressure Perforate with 4 SPF 0° phasing II 1-ll/1,q -kh,..,, ~h,-, ,-,',,. _ l~ gr. "'""' ~h~+ Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation subsequent to operation 338 407 0 850 108 332 539 0 850 125 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my Signed ~)~::;7~.~.[~j /~ Form 10-404 'i~;v. 1]-1-85 Date ? ~¢-~Sf Submit in Duplicate Feet ARCO Alasks, Inc. Subsidiary of Atlantic Richfield Company 'ELL 1PBDT CONTRACTOR REMARKS ~-~,~,~_ ~ FIELD - DISTRICT- STATE OPERATION AT REPORT TIME .... WELL SERVICE REPORT DATE r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemP'Report o1~ [ Chill Fact°r I VisibilitYou- ..,,m,,. Iwind Vel' ~. .... [Signed -- "--- STATE OF ALASKA .... ALASL. OIL AND GAS CONSERVATION COMk SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ,~ Operation Shutdown [] Re-enter suspended well ~ Alter casing F~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order © Perforate [_~ Other 2. Name of Operator ARCO Alaska. [nc. 3. Address P.0. Box 100360~ Anchoraqe, Alaska 99§10 4. Location of well at surface 13Z6' FSL, 53' FEL, Sec. 14, TllN, R8E, UM At top of productive interval 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UM At effective depth 1428' ENL, 1428' FNL, 1352' FEL, Sec. 23, TllN, 48E, UH ~lt4t~' c~, 1388' FEL, Sec. 23, T11N, R8E, UM 5. Datum elevation (DF or KB) DW 123 6. Unit or Property name Kuparuk River Unit 7. Well number 2A-10 8. Permit number 86-2 9. APl number 50-- 103 - 2005)~6 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7260 feet Plugs (measured) 6247 feet 7150 6162 feet Junk (measured) feet None None Casing ~ngth Conductor 106' Surface 2828' Production 6655' Liner 813' Size Cemented Measured depth 16" 310 SX CS 11 106' 9-5/8" 810 sxCSIII 2863' & 290 sxCSII 7" 200 sx Class G 6690' & 175 sxCSl 5" 140 sx Class G 6437'-7250' RECE!V Perforation depth: measured 6783'-6837' 6918'-6950' true vertical 5874' -5917 ' 5981 '-6006' Tubing (size, grade and measured depth) 3-1/2" (199 jts), 0-55 & 2-3/8" Packers and SSSV (type and measured depth) FHL okr @ 6310' DR nkr Fa 12.Attachments ~ue Vertical depth 106' 2773' 5799' 5597'-6239' (13 jts) J-55, tbg w/taA~C~°[~g~;884' [ TPRD_IA_CCA C¢¢t/ ~ 10~1 Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation November 1, 1986 14. If proposal was verbally approved Name of approver R. Douglas Date approved ]0/31/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge i'~ ..~ ..~,.., ',:"~ Sr. Operations Engineer Date Conditions of approval Approved by Commission Use Only Notify commission so representative may witness I Approval No. ~ Plug integrity [] BOP Test [] Location clearanceI :'. by order of .-:,t :~:` ~' Commissioner thecommissionDate//'j.~". Form 10-403 Rev 12-1-85 .... Submit in triplicate SUNDRY NOTICES INTENT It is proposed that the A Sand in Kuparuk Well 2A-10 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. PROPOSED INTERVALS (MD)' 6892'- 6902' SPF' 4 ANTICIPATED START DATE' November 1, 1986 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN,..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~, Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension '~ Change approved program [] Plugging ~ Stimulate [] Pull tubing [] Amend order ~ Perforate ~X Other 2. Name of Operator 5. Datum elevation (DF or KB) RK~ ARCO Alaska. Inc. 6. Unit or Pro~p~e'~ty name 3. Address P.O. Box 100360~ Anchoraqe, Alaska 99510 4. Location of well at surface 13%:6' FSL, 53' FEL, Sec. 14, T11N, RSE, UM At top of productive interval 1208' FNL, 1218' FEL, Sec. 23, T11N, R8E, UN At effective depth 1428' F~IL, 1428' FNL, 1352' FEL, Sec. 23, T11N, 48E, UM Alt4tg~'l~l~, 1388' FEL, Sec. 23, T11N, R8E, UM feet K;!paruk River Unit 7. Well number 2A-10 8. Permit number 86-2 9. APl number 50-- 103 - 2005~6 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7260 feet Plugs (measured) None 6247 feet 7150 None feet Junk (measured) 6162 feet Casing Conductor Surface Length Size 106' 16" 2828' 9-5/8" 6655' 7" 813' 5" Production Liner Perforation depth: measured 6783' -6837' 6918' -6950' true vertical 5874' -5917' 5981'-6006' Cemented Measured depth 310 SX CS 11 106' 810 sxCSIII 2863' & 290 sxCSII 200 sx Class G 6690' & 175 sxCSl 140 sx Class G 6437'-7250' Rue Vertical depth 106' 2773' 5799' 5597'-6239' Tubing (size, grade and measured depth) .:;, ::--. ', 3-1/2" (199 jts), J-55 & 2-3/8" (13 jts) J-55, tbg w/tail @ 6884' Packers and SSSV (type and measured depth) FHL kr ' ' 12.Attachments Description summary of proposal ~ Detailed operations program BOP sketch 13. Estimated date for commencing operation November 1, 1986 14. If proposal was verbally approved Name of approver R. Douglas Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~.- .; ~.~ ,, /, ? Sr. Operations Engineer Signed -,"~ ~' ~ ~'~ ,-' ~-~-~""~ Title Date Conditions of approval Commission Use Only Notify commission so representative may w~ ,.__. Plug integrity [] BOP Test [] Location clearance( Approved by Commissioner Approval No. by order of the commission Date /% ~/(.-]~ ~ Submit in triplicate Form 10-403 Rev 12-1-85 SUNDRY NOTICES INTENT It is proposed that the A Sand in Kuparuk Well 2A-10 be. perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. PROPOSED INTERVALS (MD)' 6892' - 6902' SPF' 4 ANTICIPATED START DATE' November 1, 1986 ARCO Alaska. In~ Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ~, INC. ATT~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. DATE O-~' ~ ~ TRANSMITTAL # 5701a Please acknowledge receipt and Open Hole Final Prints: Schl: One * of each 3N-5' 5" DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu-GR 2" Den/Neu-GR 5" Den/Neu-GR ~ 2" Den/Neu-C~ Cyberlook 3N-4 5" DIL/SFL-GR 2" DIL/SFL-GR ~~ 5" Den/Neu 2" Den/Neu 2" Den/Neu ...... ~_____~berlook 3N-3 5" DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu 3J~16 2" Den/Neu '5" Den/Neu 2" De~/Neu Cyb~erlook 5" DIL/SFL-GR 2" ' DIL/SFL-GR 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberlook 02-21-86 02-21-86 (poro) 02-21-86 (poro) 02-21-86 (raw) 02-21-86 (raw) 02-21-86 02-21-86 02-14-86 02-14-86 (poro) 02-14-86 (poro) 02-14-86 (raw) 02-14-86 (raw) 02-14-86 02-14-86 02-17-86 02-17-86 (poro) 02-17-86 (poro) 02-17-86 (raw) 02-17-86 (raw) 02-17-86 02-17-86 02-15-86 02-15-86 (poro) 02-15-86 (poro) 02-15-86 (raw) 02-15-86 (raw) 02-15-86 02-15-86 Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run Run 0190-7593 0190-7593 #1 6980-7568 6980-7568 6980-7568 #1 6980-7568 #1 6980-7568 #1 2000-7896 #1 2000-7896 #1 4111-7870 #1 4111-7870 #1 4111-7870 #1 4111-7870 #1 7200-7840 #1 1700-7986 #1 1700-7986 #1 7450-7960 #1 7450-7960 #1 7450-7960 #1 7450-7960 #1 7450-7937 #1 4453-8718 4453-8718 #1 8100-8695 #1 8100-8695 #1 8100-8695 #1 8100-8695 #1 8100-8671 ~ Oi~ & G~ Cons, Comm~ss~c An~orage Receipt Acknowledged: ~., state 'of AK, bl/se Drilling*bi NSK Clerk*bl D & M*bl Date: Rathmell*bl Vault*films ARCO Alii"". Inc. ,I · SuOs, c~a~;y ot Atlafl.cfl,cnhelglComotn? ARCO Alaska. In Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATT~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 07-14-86 TRANSMITTAL # 5701b Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole Finals Continued..., 3I-5~ 5"'DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu '~ ~. 2" Den/Neu 5" Den/Neu 2A-10 2" Den/Neu Cyberlook 2" DIL/SFL-GR (poro) (poro) (raw) (raw) 5" Den/Neu-GR (poro) 2" Den/Neu-GR (poro) 5" Den/Neu-GR (raw) 2" Den/Neu-GR (raw) Cyberlook 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run 91 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run 91 02-06-86 Run 91 02-06-86 Run 91 02-06-86 Run 91 1500-8061 1500-8061 4950-8035 4950-8035 4950-8035 4950-8035 7350-8012 6680-7132 6680-7132 6680-7107 6680-7107 6680-7107 6680-7107 6680-7107 Receipt Acknowledged: · State of AK*bl/se Drilling*bi Date: NSK Clerk*bl D & M*bl Rathmell*bl Vaul t'films ARCO illlF, l. Inc. rS · 5UDl,O~-lry Of Atlll"tttcRichllet(~Compin¥ STATE Of ALASKA · ALASKA l~L AND GAS CONSERVATION COMMI~_ .,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other'~ C0/'Y~I~_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchoraoe~ AK 99510 4. Location of well at surface 1326'FSL, 53'FEL, Sec.14, T11N, R8E, UM At top of productive interval 1208' FNL, 1218'FEL, Sec.23, T11N, R8E, UH At effective depth 1428'FNL, 1352'FEL, Sec.23, T11N, R8E, UM At total depth 1487'FNL, 1388'FEL, Sec.23, T11N, R8E, UM Perforate J~ Pull tubing 5. Datum elevation (DF or KB) RKB 1 23 ' 6. Unit or Property name K,,.nnr,,~ Riv~,r llnli~ 7. VVell number 2A-10 8. Approval number Permit #86-2 9. APl number 50m 1 03-20056 10. Pool Kuparuk River 0il Pool Feet' 11. Present well condition summary Total depth: measured 7260 feet true vertical 6247 feet Plugs (measured) N o n e Effective depth: measured 71 50 feet true vertical feet 6162 Casing Length Size Conductor 80 ' I 6" Surface 2828 ' 9-5/8" Producti on 6655 ' 7" Li net 813 ' 5" Junk(measured) None Cemented Measured depth True Vertical depth 310 sx CS II 106'MD 106'TVD 810 sx CS I I I & 2863'HD 2773'TVD 310 sx CS II 200 sx Class G & 6690'HD 5799'TVD 1 75 sx CS I 140 sx Class G 6437'-7250'HD 5597'-6239'TVD Perforation depth: measured 6783' - 6837 'MI:) true vertical 6918' - 6950'MD 5874' - 5917'TVD 5981 ' - 6006'TVD Tubing (size, grade and measured depth) 3-1/2" (199 jts), J-55 & 2-3/8" (13 jts), N-80, tbg w/tail Packers and SSSV (type and measured depth) FHL pkr ~ 6310', DB pkr ~ 6861 ', & TRDP-1A-SSA SSSV @ 1803' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History with Addendum) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ ~btr'© 15. ! hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (DAM) SWO/003 Submit in Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or worKover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska County, parish or borough North Slope Borough ILease or Unit ~ Title ' APL 25570 Completion JState Alaska Kuparuk River IWell no. 2A-10 Auth. or W.O. no. AFE 904295 Nordic 1 AP1 50-103-20056 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour Complete 3/17/86 Date and depth as of 8:00 a.m. 3/17/86 3/18/86 3/19/86 3/20/86 3/21/86 Complete record for each day reported IARCO W.I. Prior status if a W.O. 56.24% 0100 hrs. 5" @ 7250, 7150' PBTD, Tst'g BoPE 12.1 ppg gel mud Accept rig @ 0100 hfs, 3/17/86. ND tree, NU BOPE. 3½", set tst plug. Filled hole w/32 bbls diesel. to 3500 psi. Chg rams to Tst 7" csg 5" @ 7250' 7150' PBTD, Prep to drl cmt Wt. 11.7, PV 12, YP 15, PH 10, WL --, Sol 18 RIH w/retrv'g tl to 2498', circ off diesel cap. RIH, tag BP @ 6610', rel same, CBU, POH w/DP & BP. RIH w/bit & scrpr, tag cmt @ 6240', prep to DO cmt. 5" @ 7250' 6708', PU 3½" DP 12.2+ ppg gel mud Drl soft spotty cmt f/6240'-6432', tag TOL, circ well cln; has cut mud in rtns. Wt up to 12.2 ppg & circ well cln. Tst TOL to 1000 psi; OK, POH. PU 4-1/8" bit & scrpr, RIH, twisted pin off DC #20 in box of DC #19. PU 2 its, 2-7/8" DP, RIH to 6406', PU 3½" DP. Did not see any cmt @ TOL. RIH, wsh'd dn w/Kelly. 5" f/6437'-7250' 7094' PBTD, POOH w/fsh Wt. 12.3, PV 13, YP 15, PH 11.5 Wsh to 7090', drl cmt f/7090'-7094', CBU, POOH, twisted off pin in DC's, leaving 13 DC's in hole w/TOF @ 6646'. MU OS/grapple, RIH, tag & latch fsh, POOH w/fsh. 5" f/6437'-7250' 7094' PBTD, TIH f/mud displm't Cln'g pits Cunt POOH w/fsh (left ½ of bit cone in hole). Rn CET; no results.( RU & rn~B~ f/7009'-surf, RD Schl. MU bit & 5" csg scrpr, RA~w/3½" DP~ dispm't rn'g over flow nipple. Cunt RIH w/3½" DP.~ ~d_.,,T · : : : The above is correct Signature Furl r o m preparation-and dlstributl~n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations ~ire suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25570 Auth. or W.O. no. ~Tit~e AFE 904295 I Completion Nordic 1 API 50-103-20056 IAccounting Stale cost center code Alaska IWell no. 2A-10 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. 3/22/86 thru 3/23/86 Date 3/17/86 Complete record for each day reported Iotal number of wells (active or inactive) on this i Dst center prior to plugging and J bandonment of this well I our I Prlor status if a W,O. I 0100 hrs. 5" f/6437'-7250' 7094' P TD, ow/ 783 ' Diesel in tbg & ann to 6247' w/12.3 ppg Bridgesal bel RIH to 7094', wt up brine w/Birdgesal to 12.3 ppg. D~p1 well to Bridgesal. RU &~pg.rf f/6918'-6950' @ 6 SPF & f~'-6837' w/3-3/8" guns @ 12 SPF. Rn 4" gage ring/JB to 7000', POOH. RIH w/5" WL pkr assy, set @ 6851' WLM, RD WL unit. Rn 3%" x 2-3/8" CA, set pkr, shear PBR. Att to shear out sub, would not shear; sheared lockdn screws. MU new hgr, re-lnd tbg, tst to 2500 psi. Press'd to 5000 psi, ball would not shear. RU S/L unit, RIH w/1.75" blind box, att to shear w/o success. RD S/L unit. ND BOPE, NU tree. Rev circ well to diesel. Tst tbg to 1000 psi. Bled tbg to 0 psi, ball is wedged. Set BPV. RR @ 2030 hrs, 3/23/86. SSSV @ 1803', FHL pkr @ 6310', DB Pkr @ Did TD New TD Released rig Date 2030 hrs, Classifications (oil, gas, etc.) 0il I PO Depth 3/23/86 IKindOfrig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7094' PBTD Rotary Well no. 'Date Reservoir Producing Interval Oil or gasI Test time Production Oil on test r Gas'per day , , Pump size, SPM X length Choke size T.P. C,P. 'Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date ]Title For form preparation and di(tributi°n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 2/18/86 3~28/86 3/29/86 3/30/86 2A-10 Arctic Pak well w/175 sx CS I, followed by 60 bbls Arctic Pak. RU tree saver w/long mandrel; failed to seat in tbg. RU rig pmp & circ diesel @ 6 BPM thru treesaver mandrel out wing vlv. Treesaver cups not holding press. RD treesaver & pmp. RU lubr, tst to 5000 psi. RIH w/jet cutter. RU S/L, pull BPI slv f/AVA BPL lnd'g nipple. Att to flow well to tank f/cln up. NO SITP, no flow. RD Camco. Drilling Supervisor Date ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 904309 Nabors 26E ICounty, parish or borough North Slope Borough Lease or Unit ADL 25570 Title Drill IState Alaska IWell no, 2A-10 API 50-103-20056 Operator ARCO Alaska, Inc. Spudded or W,O. begun Spudded IDate 1/30/86 IH°ur Date and depth as of 8:00 a.m. 1/31/86 2/01/86 thru 2/03/86 2/04/86 2/05/86 2/06/86 Complete record for each day reported 1600 hrs. IARCO W.I, Prior status if a W.O. 56.24% 16" @ 106' 1608', (1502'), Drlg Wt. 8.8 ppg Accept rig @ 0900 hrs, 1/30/86. NU diverter sys. Spud well @ 1600 hrs, 1/30/86. Drl 12¼" hole to 1561', Navi-Drl to 1608'. 9-5/8" @ 2863' 6712', (5104'), Short trip Wt. 9.6, PV 14, YP 9, PH 9.8, WL 6.5, Sol 7 Drl & surv 12¼" hole to 2880', short trip, C&C, TOH. RU & rn 72 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 2781', FS @ 2863'. Cmt w/810 sx CS III, followed by 310 sx CS II. Displ using rig pmps, bump plug. ND diverter sys. NU & tst BOPE. RIH to 2780', tst csg; OK. DO cmt, flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 6712', CBU. 1707', 5.5°, S38.2W, 1707 TVD, 6 VS, 5S, 4W 2459', 24.2°, S28.2W, 2429 TVD, 202 VS, 182S, 86W 2820', 34.3°, S23.2W, 2744 TVD, 378 VS, 343S, 160W 3114', 37.6°, S25.2W, 2982 TVD, 551VS, 50OS, 230W 3555', 37.7°, S24.2W, 3331TVD, 820 VS, 745S, 343W 5187', 38.1°, S27.2W, 4622 TVD, 1818 VS, 1647S, 771W 6600', 37.3°, S26.2W, 5723 TVD, 2703 VS, 2432S, ll80W 7" @ 6690' 6712', (0'), PU 3½" BHA Wt. 9.6, PV 14, YP 7, PH 10, WL 6.5, Sol 8 Short trip to HWDP, strap out, CBU, TOH, LD DP & BHA. RU & rn 155 its, 26#, J-55 BTC 7" csg w/FC @ 6600', FS @ 6690'. Cmt w/200 sx C1 "G" w/l% FL-14, .5% CD-31, .3% A-2 & 1GHS FP6L. Bump plug. ND BOPE. Chg rams. 7" @ 6690' 7005', (293'), Drlg 6-1/8" hole Wt. 12.2, PV 22, YP 16, PH 9, WL 5.6, Sol 18 Tst BOPE. RIH, DO FC, tst csg to 3000 psi. DO cmt + 10' new hole. Conduct formation tst to 13.2 ppg. Drl 6-1/8" hole to 7" @ 6690' 7140', (135'), TIH Wt. 12.5, PV 32, YP 15, PH 8.5, WL 5.4, Sol 18 Drl to 7140', short trip, C&C, POH. RU Schl, rn DIL/SFL/SP/CNL/GR/FDC. RIH to drl. The above is correct Signature ~ o o p eparatio-n an~l ~$tribution, see Procedures Manual, S~'ction 10, Drilling, Pages 86 and 87. Drilling Superintendent AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish State Alaska Alaska North Slope Borough Field ILease or Unit ]Well no, Kuparuk River ADL 25570 2A-10 Auth. or W.O. no. ~Yitle AFE 904309 I Drill Nabors 26E API 50-103-20056 Operator ]A.R.Co. W.I. ARCO Alaska, Inc. 56.24% I Date Spudded or W.O, begun Spudded 1/30/86 Date and depth as of 8:00 a.m. 2/07/86 2/08/86 thru 2/10/86 2/16/86 Complete record for each day reported Iotal number of wells (active or inactive) on this i Dst center prior to plugging and bandonment of this well I our l Prlor status if a W,O. 1600 hrs. I 7" @ 6690' 7260', (120'), TIH w/lnr Wt. 12.5, PV 29, YP 15, PH 9.0, WL 5.4, Sol 19 Drl & surv 6-1/8" hole to 7260', short trip, C&C. RU & rn 16 its + mkr jr, 5", 18#, LTC lnr. TIH to csg shoe, hgr set prematurely, POOH & chg out hgr. TIH w/lnr. 5" f/7250'-6437' 7260' TD, 7150' PBTD, RR Die§el cap Fin rn'g 5" lnr w/FS @ 7250' FC @ 7199', TOL @ 6437'. Cmt w/140 sx C1 "G". POH w/rn'g tl. TIH w/bit & scrpr, POOH. TIH w/BP, set @ 6225'. Circ out green cmt. Set BP @ 6222' spotted 4 sx of sand on top. POH, LD 3½" DP. Put 2000' diesel cap in 7" csg. ND BOPE. NU tbg head. RR @ 1100 hrs, 2/8/86. Arctic packed well w/175 sx CS I. Old TD New TD Released rig Date ll00 hrs. Classifications (oil, gas, etc.) O±l I PB Depth 7260' TD ]Kind of rig 2/8/86 Type completion (single, dual, etc.} Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7150' PBTD Rotary Welt no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, sPM X length Choke size T.P. C,P, Water % GOR Gravity Allowable Effective date corrected The above is correct For for~ preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 2/18/86 2A-10 Arctic Pak well w/175 sx CS I, followed by 60 bbls Arctic Pak. Drilling S~pe~intendent / Da~e ' Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · O~ERATOR; '~LL~ NABS' AND 'NUMBER Reports and Materials to be received by.- Date Required Date Received Remarks Completion Report ~ell History Samples ,, ~~P/ ~-~,,, w r ~ g ' Core Chips , .... _ Core Description ...... Registered Survey Plat Inclination Survey ~ ~- Surve~y~ ' Drill Stem Test Reports~ , , Production.. Test Reports - Lo~ Run '~ ~'., /~, "~" STATE OF ALASKA ~ ALASKA O,~_ AND GAS CONSERVATION CO';-i 7/IlSSION ~-~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-2 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20056 4. Location of Well atsurface 1327' FSL, 53' FEL, Sec.14~ T11N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 123' RKB ADL 25570 ALK 2668 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2A-10 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. February , 19. 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 1600 hfs, 1/30/86. Drld 12-1/4" hole to 2880'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 6712'. Ran, cmtd, & tstd 7" csg. Dr]d 6-1/8" ho]e to 7140'. Ran logs. Cont'd drlg 6-1/8" hole to 7260'TD (2/6/86). Ran, cmtd, & tstd 5" csg. Set bridge plug ~ 6222'. Spotted 4 sx of sand on top of plug. PBTD = 7150'. Secured well & RR ~ 1100 hfs, 2/8/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 106'. Installed w/310 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 2863'. Cmtd w/810 sx CS Ill & 310 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 6690'. Cmtd w/200 sx Class G & 175 sx CS I. 5", 18.0#/ft, L-80, LTC csg f/6437' - 7250'. Cmtd w/140 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/CNL/GR/FDC - Depths not available 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE -Report i~n-this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. c~ ,n ~n~ I~AM/MRI? Ruhmit in dt. Dlicate ARCO Alaska. inc. Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 RETURN TO: ARco ALASKA, LNC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 03-04-86 2~U%NSMITTAL # 5588 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of ~his transmittal. OH Lis Tapes Plus listings/ SCHL/ One of each ~'~3N-4 02-14-86 REF #71279 ~ ~3N-~ ' 02.-07-86 REF #71266: ~3N-2 01-27-86 REF # 7127'2~ '~3J-16 02-15-86 REF #71278~ ~3I-5 02-09-86 REF #71273~ ~'~I-4 02-02-86 R~F #71239~- 3I-3 01-26-86 REF #71242 ~ ~'~2A-11 01-28-86 REF ~.~71243~ ~2A-10 02-06-86 REF #71244~, ~ 2A-9 02-17-86 REF #71280~_.' Receipt Acknowledged: STATE OF_ AK .... ARCO Alaska. Inc. ,l · SuOl~·ry of Atlarlt,cRicttl~el4ComDln}, MEMORANDUM Statr' of Alaska ALAS¥.A OIL D GAS CONSERVATION COMMISb~JN /o: C. V~~t~erton DATE: February 7, 1986 Cha i ~n3~\---~-~--/. F~tENO.' D.ADA. 10 THRU: Lonnie C. Smith'/'~ TELEPHONE NO.' Commissioner FROM: Doug Amos ~'~ Petroleum Inspector SUBJECT: BOPE Test ARCO KRU 2A-10 Permit No. 86-02 Kuparuk River Field Saturday, February 1, 1986: After witnessing the BOPE Test at ARCO ~-~-U-16-24' i traveled't° ARCO KRU 2A-10 to witness the BOPE test. The testing commenced at 7:00 PM and was concluded at 8:20 PM. were no failures and I filled out an A.O.G.C.C. BOPE Inspection Report which is attached. There In summary, I witnessed the successful BOPE test at ARCO KRU 2A-10 well. Attachment 32-001 A( Rev ~e~' . Well' ~ '~~'' ~ -~o i" · Representative ~ , Permit # ~/~casi.g set ~ Rig #~epresentativ-- 3 ,,, AC~MU~TOR SYST~ inspector~- ' "~"~ "!'?~ope~aEor'- ~ 'A'~_~ ~ - Location: Sec ~ T [% ~A R ~ M t~.~A . Drilling C0n'tracto~ ~O~ Location, General Well Sign General Housekee Reserve pit Rig Full Charge Pressure ps ig PresSure After Closure \~OO psig BOPE Sta6k Annular Preventer / I · D~ 200 psig Above Precharge Attained:. min~D~ sec ~ ~ Full Charge Pressure Attained: ~_ min ~ sec Controls: Master ~ ~ Remote ~. Blinds switch.cover Kelly and Floor Safety Valve~ Upper Kelly I.~' Test Pressure ~,~0 Blind Rams Choke Line Valves H. C. R'o Valve Kill Line Valves~'~~ Check Valve Test Pressure Lower Kelly ~ ~ Test Pressure Ball Type ! ~Test Pressure Inside BOP I ~est Pressure ChokeManifold I Test Pressure No..Valves No. flanges Adjustable Chokes Hydrauically operated choke. Test Time. '1 hrs. '~.D V~.~ ~ Test Results: Failures , ~lays and .l~ Il Repair or Replacement of failed equipment to be made wit. hin Inspector/Commission office notified. Remarks: Dis tribution orig. - AO&GCC' cc - Operator cc - Supervisor InsPector ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 22, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2A Pad (Wells 9 - 12) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, ~J. Gruber Associate Engineer JG/tw GRU13/L19 Enclosure If ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany RECEIVED JAN 2 7 198. Alaska Oil & Gas ISons. Gommission Anchorage "- WELL 9- Y = 5,960,687.74 X = 498,540 70 - LAT 70° 18' 13.7715" I --'" r"-- LONG. 150000'48.387" ! ~ ! 0. G. 87.6' PAD 92.2' i i , ; I , i I 1,266' FSL 53' FEL II · 014 i WELL I0- [ i i°· 0 15 t I 9 · 0 16 i , Y= 5,960,747.76 X = 498,340.70 LAT. 70°18' 14.3619 I ~ LONG. 150000'48.388'' i O.G. 88.0' PAD 92.3' ~ i 1,326' FSL 53' FEI ~ ' WELL II- Y= 5,960,807.80 I X = 498,540.85 , LAT. 70° 18 14.9525 ' ! LONG. 150° 00'48.383" ' O.G. 88.3' PAD 92.3' 70 : 02 : 1,387' fSL 53' FEL 60 ~ i 03 i 50 ~ 04 l WELL 12_- : ! : i Y = 5,960,867.74 i " i ! X = 498,340.71 · ! I ~ LAT. 70° 18' 15.5420" i LONG. 150° 00'48.388" ~ , O.G. 88.5' PAD 92.0' __.~446' FSL 5:5' FEL 14113 .r~ . LOCATED IN PROTRACTED SECTION 14, TIIN, RSE, ~ o') '-'; ~ UMIAT MERIDIAN. --- r,. ° ~ ;~[49th NOTES L.t.J cu ~ ~ ~...r.,,....-., .... ,.,..,,J'... I. COORDINATES ARE A.S.P., ZONE 4. U :~ ~ ~ ,,, <., 3. HORIZONTAL POSITIONS BASEDON 2A-NORTH 8~ 2A-SOUTH ~ "-3 PER L.H.D. 8~ ASSOC. DW-G. NO. NSK-6.201 - d l. L.H.D. 8~ ASSOC. DWG. NO. NSK- 6.201 -dl. 5. O.G. ELEVATIONS INTERPDLATED FROM S/C DWG. ~' '~,,'-~r0/'£$~/0.~1~ _~__~ CED-- BAO0- 3001 rev. ~ ~ · :,, D.S.2~, i LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY'MADE UNDER MY D~RECT SUPERVISION AND THAT ALL DETAILS 14 ARE CORRECT AS OF D.S. 2-A ~ ARCO Aloska, Inc. Kuporuk Project North Slope Dr~lting '-, DRILL SITE 2..A " / IIII1 CONDUCTOR AS-BUILT t LOCATIONS .. -'~ "~llll& Date' 17.'30'85 I Scale' AS SHOWN Drawn By' ~ j Dwg. NO. NSK- 85-38 January 6, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kupa~uk River unit ~2A-10 ARCO Alaska, Inc. Permit No. 86-2 Sur. Loc. !327.'FSL, 53'FEL, Sec. 14, TllN, RSE, UM. Btmhole Loc. 1509'FNL, 1410'FEL, Sec. 23, Tll~, RSE, IN. Dear Mr. Kewin: Enclosed is the' approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V ~r~y~ trulv_~ours, ,; ./~.m /..'~ . : ;"'~ ." / i /,z,- :.~,, ~,,-~,_.:..~,..-,.--- C. V. ChattertOn Chairman of Alaska Oil and Gas ConServation Con~nission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery .. ARCO Alaska, Inc. Post Office Bo.. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2A-10 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill 2A-10, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on January 24, 1986. If you have any questions, please call me at 263-4970. ~~/~rely, ~ Regional Drilling Engineer JBK/JFB/tw PD/L198 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA - ALASKA O,' AND GAS CONSERVATION CON, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL FX!X REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~][X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. SERVICE [] STRAT~GRAPH lC S,NGLE ZONE ~ MULTIPLE ZONE 3. Address P. 0. Box 100:360, Anchorage, Alaska 99510 4. Location of well at surface 1:327' FSL, 5:3' FEL, Sec.14, T11N, RaE, UM At top of proposed producing interval 124:3' FNL, 128:3' FEL, Sec.2:3, T11N, R8E, UM At total depth 1509' FNL, 1410' FEL, Sec.2:3, T11N, RaE, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 12:3', PAD 92' I ADL 25570 ALK 2668 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name - Kuparuk River Unit:.'~ 10. Well number 2A-10 11.Fieldandpool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles :3771' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7289' MD, 6248' TVD feet 2560 20. Anticipated pressures KICKOFF POINT 1602 feet. MAXIMUM HOLEANGLE 38 o (see 20 AAC 25.035 (c) (2) 19. If deviated (see 20 AAC 25.050) 15. Distance to nearest drilling or completed 2A-11well 60' @ surface feet 18. Approximate spud date 01/24/86 2977 psig@__80° F Surface 3422 psig@~ _58,75 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Casing Weight Grade Coupling Length MD TOP TVD (include stage data) SIZE '-~ole 24" 1__2-1/4" 8-1/2" 6-1/8" 16" 62.5# H-40 9-5/8" :36.0# !-55/HF-EI 7" 26.0# -55/HF-EI 5" 18.0# L-80 Weldi W BTC [W BTC LTCI 80' :32' 2206' 31 ' 31 ' 6683' 789' 32' I I 31 ' I 31 ' 6500' 5629' MD BOTTOM TVD 1121 112' 22371 2225' 6714~ 5808' 72891 6248' ± 200 cf 810 sx CS III & 310 sx Class "G" 200 sx Class "G" 100 sx Class "G" 22. Describeproposed program: ARCO Alaska, Inc., proposes ~o drill a Kuparuk River Field developmen~ well ~o approximately 7289'ND(6288'TVD). Selected intervals will be logged. A 20", 2000 psi annular diver~er w~ll be installed on ~he 16" conductor while drilling ~he surface hole. The 1:3-5/8", 5000 psi, RSRRA BOP s~ack will be installed on ~he 9-5/8" surface casing. The s~ack and rela~ed equipmen~ will be ~es~ed ~o :3000 psig upon installation and weekly ~hereaf~er. Due ~o gas injection on 2A Pad, Kuparuk "C" Sand pressures are higher ~han normal. To maintain wellbore integrity and safe~¥, ~he 7" casing will be se~ 100' above ~he ~op of ~he Kuparuk Sands. A 5" production liner will be run ~o TD. Expected aaxi~um surface pressure is 2977 psi. Surface pressure is calculated wi~h an unexpanded gas bubble a~ surface, including ~empera~ure effects. Casing will be ~es~ed ~o :3500 psi prior ~o releasing ~he drilling rig. Non-freezing fluids will be lef~ in uncemen~ed annuli ~hrough ~he permafros~ interval. 2A-10 will be 60' away f~o~ 2A-11 a~ ~he surface. (continued on a~ached shee~) 23.1hereb/~y that the fo,~g is true and correct to the bestD/ /~j~~ I/ ):~/~ of my knowledge __SIGNE TITLE Regional Drilling Engineer DATE The spa~:~;~io~v~rr~iCo/mi s~lon use / cO IT O S Samples required Directional Survey required APl number [] YES eNO [~LY ES [] NO 50-/~ '~° Permit number SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE January 6; ]9R6 by order of the Commission Mud Icg required []YES [~x!O Approoal date ~'~ -,~' ; I ~ ~01/06/86 ( \_.?.f ~ 'PD/~'9~/ /" / Form 10-401 Submit in triplicate D~,, ~ d O~ PERMIT TO DRILL 2A-10 (cont'd) There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. E-C-~-~".TVD=5875 THD-681-4-1DEP-28'49_ ..... ~ -~-~T~RGET'~',CNTR'--:--TVD-$OB3--~t"ID-6952 DEP=2955 .... T -! r- i ~ c KUPARUK tRI VER UNIT 20" DIVESTER SCHEMATIC i iiii ii DESCR I PT I ON i i. 16" CCt, OUCTOR. 2. TA~O STARTER HEAD. 5. TAha(O SAVER SUB. 4. TANKO LOWER ~ICK-C~CT ASSY. 5. TA~O U~ER ~]~-C~CT ASSY. 6. 20" 2~ PSI ~ILLI~ ~/I0' ~TLETS. ?. I0' HCR B~LL V~LYES ~/10' DIVERTER LI~S, VALVES ~EN AUT~TICALLY UP~ CLARE A~AR PREVE~ER. 8. 20' 2~ PSI A~LAR P~~. '7 4 MAINTENANCE & OPERAT.] ON · I. UPON INITIAL INSTALLATIC)N, CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. 2. CLOSE AhI'~LAR PREVENTER Ah[:) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. :5, CLOSE AM'~LAR PREVENTER IN THE EVENT 'THAT AN INFLUX OF WELLBO;~ " FLUIDS OR GAS IS DETECTED. !F .. NECESSARY, h4ANIJALLY OVERRIDE CLOSE - APPROF~ ! ATE VALVE TO ACHIEVE ~IND DIVERSION. DO NOT SHUT IN ~ELL < < '1 L_ > > ACC%M. LATOR CAPACITY TEar I~V-r..L Wi'TH ~~'C FLLI~ ~ Tt-lkT A_,"'~__M,.I_AT~ ~ IS, ~ PSI 5. C:P..S~-~VE T]lv~., TI-EN 1:::1_C3~ AIL I.,I~TS &L.L I.t~T$ N;~ ~ WITH ~]N~ ~ CF'F. ,4. i~C:I:::I~ 1~ ~ t:~I~RTo TiE AC;I:::~'I'AB/.E LI::IP~I~ LIMZT 5 4 2 KUPAEUK RECEiVqg I5--5/E" E4)P, STACK T~ST i. F'3ll ~ ~I'AC::K ~ C3.~ ~F6L.D WITH D-~I:::X THAT ALL ~ ~ ~ :IN ~vt L!-EAD ~ FLLLY F~FI~TJ~D. ~A7 ~ I:"L. LK~ 2N ~FL~ ~EAD WITH ~~ ~ ~ ~ IN k~ ~. 6. ~T TO ~ ~l ~ ~ ~1 ~ IN ~ 4. ~Y T~ F~i~Y ~~ ~ ~LY. A!~ska 011 & Gas Cons..~.- .... 16" CONDUCTOR BOP STACK m :>(2) ,LOS ( thru 8) (3) (4) Casg (1'0 and thru 2'1) (22 thru 26 es.les.®®. .to be located in a defined'pool ........................... .... 3. Is well located proper distance from property line .................. Is well located proper distance from other wells ................. '... 4. :~S:Suffi'cient Undedicated. acreage'available in this pool ... (i - · · · t deviated and-is wellbore included ..:. . ;Is operator-the only affected party_. ............... - ................. 8. ..Can permit be approved before ten-day wait .......................... _ . 9. Does operator have a bond in force .......... , ....................... Is conServation order .needed ' a eeee.e®e®eeeeee®eee®eeeeeeeeeeeeeeeeee Is' administrative approval needed · ..eee®eee.e®®eeeeeeeeeee.eeeeeeeee. Is the lease number appropriate ....................... Is conductor string provided ........................................ Is enough cement used to circulate'on conductor and surface .......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ................ Will surface casing protect fresh water zones ..... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ' Dooo nOPE 'rev° ~ufficion~ pr~.,ur, ra~i..g- T.~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. 10. 11. 12.- 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Additional requirements · eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Additional Remarks: /4),_F' /. /.. a/}-/D /,U//-.]._ S~,. ~/~z~'~/~D/~ o~/~-11 /~Z)/P/ Ho T- s u e~ 17--F~) 1.-I , Geology ~ Engineerin~: . WVA~_~_' ~ HaH i~z~.~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,%0,0° i ' g $O /I)6o o,0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. L L S T ~ ~ ~ RECEIVED MAR 1 2 1986 ~l~$ka Oil & Gas Cons. Commission Anchorage LV~ 3'~n dO2 V::~ZFZ!3;~T:],~; L~ST",~' '"" ~" ~', o A S E ! 'irt "r' y o = - & T,':': ';; T ~'=- roiE ,~;",~ : i ~-! 3 333 30 O 'O 0 ~ 055 -3j'4: N. S~]o:: ,.9..3 JO ST:~T: &~SK&'- 333 -T~Y: JS~ 033 3:3 JO5 055 '3'] 3 3'33 02 3 355 4 W: -' TY'~: ~,.J~!"* = :" -~;~.7,'"' =LJiD LDSS = ~,::.;. '",; '~ T 7 1 X = ::~, i !"4 3 ~NTRY 5L83qS 73 3 :,3 '" ,.~ 3 3 ! $1Z: & i 4 i 4 I 4 ! 4 ! ~- i ~ i 4 I ! I i 03 5~ 003 30 O 000 OOO 03.3 330 003 .'33 ,.3 0,33 033 'D 0 O 003 333 (3CT~L) ~,00 O03 ~ OOO O00OO000000 0003'3 O 3OiD 00 O0333030000 O00~OOOOO00 00 ~ 3300 O 0 ~ 0 00033300000 OOODO00~OOO 00000003000 003333030 0 0 033303x33 O00 :3 O 0 O O O 33 :D 0 O 33030303030 -,ffDf ", 30,",. 00..3¢, <.,=~ S? -74. 7227 ':", .,'i 3 .5 ,.'~ · 15:4. '73 '"_, ,,:';' "i 3 3.5 ~:.)3 iL 3 :35 ~, 3.53 ii 0 : 'C 1 :.. 0.0 t 12 !< ~ -:.", T . . 5 E, 7 5 ! L ¢ ?!.5'~9~ -...,.-,. 5 5 15 T~, 557'5 =C'4_ !!'4.0i73 3.2~71 6 50. ':~ l ? - 3.3 :: 5 Z 114.5273 3,4531 4,7:545 55.4D23 1552.557= 59.5~30 2.5975 7. :5 :: 75 53.27'73 3.5509 15.0398 7 !. 5 .~ '):3 3.5'147 IL~ :ALi r ,'hL l ~,LI TLq iL,I RU.-<. ,3,.1355 5.1257 3.2151 2q. 2~ 4.8992 2 ,. 9005 I '3.0098 :.31 5 5.0789 1.53~t !0.5~957 3.~313 5.0710 3.~030
