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Home My WebLink About220-032DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20656-60-00Well Name/No. KUPARUK RIV UNIT 1B-10L1Completion Status1-OILCompletion Date10/16/2021Permit to Drill2200320Operator ConocoPhillips Alaska, Inc.MD9905TVD6373Current Status1-OIL1/24/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/ResNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF11/12/20218602 9905 Electronic Data Set, Filename: 1B-10L1 GAMMA RES.las35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 2MD Final Log.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 5MD Final Log.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 5TVDSS Final Log.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 01.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 02.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 03.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 04.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 05.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 06.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 07.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 08.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 09.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 10.cgm35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 GAMMA RES.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 01.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 02.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 03.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 04.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 05.ASC35939EDDigital DataMonday, January 24, 2022AOGCCPage 1 of 4PB11B-10L1 GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20656-60-00Well Name/No. KUPARUK RIV UNIT 1B-10L1Completion Status1-OILCompletion Date10/16/2021Permit to Drill2200320Operator ConocoPhillips Alaska, Inc.MD9905TVD6373Current Status1-OIL1/24/2022UICNoDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 06.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 07.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 08.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 09.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1_ PWD Log Run 10.ASC35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 2MD Final.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 5MD Final.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 5TVDSS Final.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 01 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 02 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 03 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 04 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 05 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 06 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 07 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 08 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 09 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 10 PWD.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 NAD27 Definitive Survey.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 NAD27.txt35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 NAD83 Definitive Survey.pdf35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 NAD83.txt35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 2MD Final Log.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 5MD Final Log.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 5TVDSS Final Log.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 01 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 02 PWD.tif35939EDDigital DataMonday, January 24, 2022AOGCCPage 2 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20656-60-00Well Name/No. KUPARUK RIV UNIT 1B-10L1Completion Status1-OILCompletion Date10/16/2021Permit to Drill2200320Operator ConocoPhillips Alaska, Inc.MD9905TVD6373Current Status1-OIL1/24/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYCompletion Date:10/16/2021DF11/12/2021 Electronic File: 1B-10L1 Run 03 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 04 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 05 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 06 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 07 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 08 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 09 PWD.tif35939EDDigital DataDF11/12/2021 Electronic File: 1B-10L1 Run 10 PWD.tif35939EDDigital Data0 0 2200320 KUPARUK RIV UNIT 1B-10L1 LOG HEADERS35939LogLog Header Scans0 0 2200320 KUPARUK RIV UNIT 1B-10L1 PB1 LOG HEADERS35940LogLog Header ScansDF11/10/2021 Electronic File: 1B-10L1PB1 NAD27 Definitive Survey.pdf35940EDDigital DataDF11/10/2021 Electronic File: 1B-10L1PB1 NAD27.txt35940EDDigital DataDF11/10/2021 Electronic File: 1B-10L1PB1 NAD83 Definitive Survey.pdf35940EDDigital DataDF11/10/2021 Electronic File: 1B-10L1PB1 NAD83.txt35940EDDigital DataMonday, January 24, 2022AOGCCPage 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20656-60-00Well Name/No. KUPARUK RIV UNIT 1B-10L1Completion Status1-OILCompletion Date10/16/2021Permit to Drill2200320Operator ConocoPhillips Alaska, Inc.MD9905TVD6373Current Status1-OIL1/24/2022UICNoComments:Compliance Reviewed By:Date:Date CommentsDescriptionRelease Date:4/1/2020Monday, January 24, 2022AOGCCPage 4 of 4no electrical logs run in PB1M. Guhl 1/24/2022 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: 8. Date TD Reached: 16. Well Name and Number: 9. Ref Elevations:KB: 17. Field / Pool(s): GL:BF: 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: GR/Res 23. BOTTOM 20" H-40 80' 13-3/8" L-80 2272' 9-5/8" L-80 6837' 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.): Production for Gas-MCF: Test Period Casing Press:Calculated Gas-MCF:Oil Gravity - API (corr): Press.24-Hour Rate 50-029-20656-60-00 Kuparuk River Field/ Kuparuk River Oil Pool P.O. Box 100360, Anchorage, AK 99510-0360 220-032 ADL 25648 10/9/2021 98' Sr Res Eng Gas Lift Perforations at 8818' -8870' MD and 6350'-6397' TVD Unlined Lateral 8821'-9905' MD and6353'-6373' TVD Sr Pet GeoSr Pet Eng no sample taken Oil-Bbl: Water-Bbl: 2644MCFBOPD 2308 WPD203 psi 1083 psi 10/25/2021 Flow Tubing BWPD 508 MCF192 BOPD Water-Bbl: PRODUCTION TEST 10/23/2021 Date of Test: Oil-Bbl: Gas-Oil Ratio: Per 20 AAC 25.283 (i)(2) attach electronic information 47 surf. 91.5 72 80' Surf. 9358' 1600 sx Fondu & 400 sx ASII GRADE 551562 551190 TOP SETTING DEPTH MD Surf. 1799' MD / 1696' TVD HOLE SIZE AMOUNT PULLED suspension, or abandonment, 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 if necessary surf. 17-1/2" 280 sx ASII surf. CEMENTING RECORD 5974568 SETTING DEPTH TVD 5974166 TOP N/A 9905' MD/ 6373' TVD ALK 466 3549' MD / 2931' TVD 8821' MD/ 6353' TVD 549138 5969647 CASING WT. PER FT.BOTTOM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/16/2021 KRU 1B-10L1/ KRU 1B-10L1PB1 30" Surf. 2547' 8945' MD4-1/2"' x 3-1/2" x 2.875" SIZE DEPTH SET (MD) 8423' MD/ 6002 TVD PACKER SET (MD/TVD) 2115 sx Class G cement12-1/4" 10/8/2021 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 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, TUBING RECORD Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 4a. Location of Well (Governmental Section): Surface: 494' FNL, 1301' FEL, Sec. 9, T11N, R10E, UM Top of Productive Interval: 869' FNL, 1166' FWL, Sec. 3, T11N, R10E, UM Total Depth: 1268' FNL, 790' FWL, Sec. 3, T11N, R10E, UM Hours Tested: 19 Choke Size: 72/64ths " By Hugh Winston at 3:40 pm, Nov 12, 2021 RBDMS HEW 11/15/2021 Completion Date 10/16/2021 HEW - L1 only, none in PB1 MG GDSR-11/15/21DLB 11/18/2021 VTL 01/24/2022 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 3549' 2931' Top of Productive Interval 8821' 6353' 8865' 6392' TD 9905' 6373' Kuparuk C3 31. List of Attachments: Summary of Operations, Wellbore Schematic, Definitive Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Shane Germann Contact Email:shane.germann@conocophillips.com Authorized Contact Phone: (907) 263-4597 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: 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). 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. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. 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. 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. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, 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). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: Shane Germann Senior CTD Engineer 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS 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, 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. Formation at total depth: TD Kuparuk C4 1B-10L1PB1 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Shane Germann DN: O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@cop.com Reason: I have reviewed this document Location: your signing location here Date: 2021.11.10 12:05:07-08'00' Foxit PDF Editor Version: 11.0.0 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,975.0 6/7/2018 1B-10 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install Inner Wedge 9/25/2021 1B-10 famaj Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.94 Top (ftKB) 31.3 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 91.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.35 Top (ftKB) 30.3 Set Depth (ftKB) 2,547.0 Set Depth (TVD) … 2,271.9 Wt/Len (l… 72.00 Grade N-80 Top Thread BTC Casing Description PRODUCTION OD (in) 9 5/8 ID (in) 8.86 Top (ftKB) 28.3 Set Depth (ftKB) 9,358.4 Set Depth (TVD) … 6,837.2 Wt/Len (l… 47.00 Grade L-80 Top Thread BUTT Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.6 Set Depth (ft… 8,477.4 Set Depth (TVD) (… 6,049.5 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 23.6 23.6 0.08 HANGER 3.910 13.625 FMC tc1Aems FMC 13 5/8 x 4 1/2" New Standard Big Bore Tubing Hanger W/ 5" RH Acme top 1,799.4 1,695.5 42.94 SSSV 3.812 6.923 Camco TR- MAXX- 5E Camco 4 1/2" TRMAXX-5E 3.812" SSSV 1797' 1,809.4 1,702.7 43.04 XO REDUCING 3.833 4.500 XO Pup 4 1/2" IBTM Box x 3 1/2" EUE-Mod Pin 8,451.7 6,027.1 29.40 SBE 2.990 3.980 BAKER 80/40 PBR Seal assy Baker 3 1/2" EUE seal Assy 25.67' OAL buried below liner top New up Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 8,423.2 Set Depth (ft… 8,902.5 Set Depth (TVD) (… 6,425.4 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 8,423.2 6,002.3 29.55 PACKER 6.120 8.440 Baker Baker 9 5/8" x 3-1/2" SLZXP Liner top packer - Left in hole down 8,451.1 6,026.6 29.40 PBR 4.000 6.500 Baker Seal Bore Extension (3' space out off tag) 8,835.4 6,365.8 27.32 TANDEM WEDGE 2.992 8.250 Northern Solutions Outer Wedge Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 8,850.0 6,378.7 27.27 NIPPLE 2.813 4.480 X Nipple HES 3 1/2" x 2.813" X nipple Profile (SN:) 8,860.4 6,388.0 27.23 TANDEM WEDGE 2.992 8.250 Northern Solutions Outer Wedge Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 8,875.0 6,400.9 27.18 NIPPLE 2.813 4.500 X Nipple HES 3 1/2" x 2.813" X nipple Profile (SN:) 8,894.5 6,418.3 27.10 NIPPLE 2.813 4.500 X Nipple HES 3 1/2" x 2.813" X nipple Profile W/ RHC Plug Installed (SN: 2727A-4-8) 8,895.4 6,419.1 27.10 MULE SHOES 3.640 8.500 Baker Poorboy Overshot Baker 3 1/2" x 9 5/8" Poorboy Overshot (6.77' Swallow) Tubing Description Tubing – Production String Ma… 8.66 ID (in) 3.25 Top (ftKB) 8,901.1 Set Depth (ft… 8,945.3 Set Depth (TVD) (… 6,463.5 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 8,909.6 6,431.8 27.05 SLIDING SLEEVE 2.750 5.750 BAKER CMU SLIDING SLEEVE; SEIZED IN CLOSED POSITION 12/8/2007 8,919.6 6,440.6 27.01 XO REDUCING 2.875 3.500 CROSSOVER 3.5 x 2.875 8,921.4 6,442.3 27.00 SEAL ASSY 2.440 3.400 BAKER GBH 80-32 LOCATOR SEAL ASSEMBLY 8,922.3 6,443.1 27.00 PACKER 3.250 8.660 BAKER D PERMANENT PACKER 8,937.1 6,456.3 26.95 NIPPLE 2.250 3.668 OTIS XN NO GO NIPPLE 8,944.5 6,462.9 26.92 SOS 2.441 2.875 BAKER SHEAR OUT SUB Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,795.0 6,329.9 27.44 FISH EV Camera/Shroud/UQ and LQ/25' 2.0" CT 10/12/2021 0.000 8,863.0 6,390.3 27.22 WHIPSTOCK 3 1/2" NORTHERN SOLUTIONS INNER WEDGE. TOWS SET AT 8,848' TIED INTO K1 MARKER. (8858' TIED IN TO TUBING TALLY/8863' TIED IN TO SCHEMATIC). OAL 12.1'. 9/25/2021 0.000 8,875.0 6,401.0 27.17 X-LOCK W/ FLOW THRU SUB 2.81 X LOCK (W/ PACKING), & FLOW THROUGH SUB (OAL 18.5") 4/3/2020 1.750 8,891.0 6,415.2 27.12 CEMENT RETAINER (ME) WEATHERFORD FH1 RETAINER, 2.75" OD X ( OAL=1.46 ) 3/30/2020 0.000 1B-10, 11/8/2021 1:27:21 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 Production Casing Cement; 8,870.0 ftKB APERF; 8,959.0-8,979.0 PACKER; 8,922.3 Production Casing Cement; 8,925.0 ftKB Cement Squeeze; 8,901.0 ftKB SLIDING SLEEVE; 8,909.6 Cement Squeeze; 8,894.0 ftKB Cement Retainer; 8,904.0 Cement Squeeze; 8,904.0 ftKB CHEM CUT; 8,901.0 NIPPLE; 8,894.5 X-LOCK; 8,894.0 CEMENT RETAINER (ME); 8,891.0 X-LOCK W/ FLOW THRU SUB; 8,875.0 NIPPLE; 8,875.0 WHIPSTOCK; 8,863.0 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10 ... TD Act Btm (ftKB) 9,403.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065600 Wellbore Status PROD Max Angle & MD Incl (°) 59.73 MD (ftKB) 6,300.00 WELLNAME WELLBORE1B-10 Annotation Last WO: End Date 6/28/2019 H2S (ppm) 40 Date 8/12/2016 Comment Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,894.0 6,417.9 27.11 X-LOCK 2.81 X LOCK, NO PACKING, W/ FLOW THROUGH SUB (OAL 18") 3/26/2020 1.750 8,901.0 6,424.1 27.08 CHEM CUT 2 3/8" Chemical cut. 6/26/2019 0.000 8,904.0 6,426.8 27.07 Cement Retainer Set Weather Cement Retainer (OAL 1.46') 10/5/2019 0.000 Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 2,859.1 47.15 GAS LIFT 5.968 2.915 Camco MMG 2,509.8 2 5,127.3 57.06 GAS LIFT 5.968 2.915 Camco MMG 3,810.4 3 6,733.2 53.33 GAS LIFT 5.968 2.915 Camco MMG 4,654.6 4 7,645.5 34.06 GAS LIFT 5.968 2.915 Camco MMG 5,342.0 5 8,401.1 29.66 GAS LIFT 5.968 2.915 Camco MMG 5,983.1 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,859.1 2,509.8 47.15 Schlum berger Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,274.0 8/31/2021 2 5,127.3 3,810.4 57.06 Schlum berger Camco MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 8/31/2021 3 6,733.2 4,654.6 53.33 Schlum berger Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 4 7,645.5 5,342.0 34.06 Schlum berger Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 5 8,401.1 5,983.1 29.66 Schlum berger Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,818.0 8,870.0 6,350.3 6,396.5 C-4, C-3, 1B-10 4/17/1994 4.0 RPERF 3 3/8" Hyperjet; 60° phasing 8,959.0 8,979.0 6,475.8 6,493.6 C-1, UNIT B, 1B -10 4/17/1994 6.0 APERF 3 3/8" Hyperjet; 60° phasing 9,128.0 9,138.0 6,627.5 6,636.6 A-5, 1B-10 2/4/1982 4.0 CMT SQZ 9,146.0 9,158.0 6,643.9 6,654.7 A-4, 1B-10 2/4/1982 4.0 CMT SQZ 9,158.0 9,178.0 6,654.7 6,672.9 A-4, 1B-10 2/4/1982 4.0 CMT SQZ Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 1/21/2008 8,818.0 8,870.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,870.0 9,100.0 6,396.5 6,602.2 Production Casing Cement 10/5/2019 8,925.0 8,975.0 6,445.5 6,490.1 Production Casing Cement 10/5/2019 8,904.0 8,944.0 6,426.8 6,462.4 Cement Squeeze 10/5/2019 8,894.0 8,922.3 6,417.9 6,443.1 Cement Squeeze PUMPED TWO COIL VOLUMES OF FRESH WATER FOLLOWED WITH 69 BBLS OF 15.8# PPG CEMENT 3/30/2020 8,901.0 8,922.3 6,424.1 6,443.1 Cement Squeeze 3/30/2020 Notes: General & Safety End Date Annotation 9/25/2021 NOTE: WELL SCHEMATICS LISTS ALL DEPTHS 5' DEEPER THAN TUBING TALLY IN WELL FOLDER. 1/29/1998 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION 1B-10, 11/8/2021 1:27:22 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 Production Casing Cement; 8,870.0 ftKB APERF; 8,959.0-8,979.0 PACKER; 8,922.3 Production Casing Cement; 8,925.0 ftKB Cement Squeeze; 8,901.0 ftKB SLIDING SLEEVE; 8,909.6 Cement Squeeze; 8,894.0 ftKB Cement Retainer; 8,904.0 Cement Squeeze; 8,904.0 ftKB CHEM CUT; 8,901.0 NIPPLE; 8,894.5 X-LOCK; 8,894.0 CEMENT RETAINER (ME); 8,891.0 X-LOCK W/ FLOW THRU SUB; 8,875.0 NIPPLE; 8,875.0 WHIPSTOCK; 8,863.0 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD 1B-10 ... WELLNAME WELLBORE1B-10 Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 2,859.1 47.15 GAS LIFT 5.968 2.915 Camco MMG 2,509.8 2 5,127.3 57.06 GAS LIFT 5.968 2.915 Camco MMG 3,810.4 3 6,733.2 53.33 GAS LIFT 5.968 2.915 Camco MMG 4,654.6 4 7,645.5 34.06 GAS LIFT 5.968 2.915 Camco MMG 5,342.0 5 8,401.1 29.66 GAS LIFT 5.968 2.915 Camco MMG 5,983.1 1B-10L1, 11/8/2021 1:27:23 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10L1 ... TD Act Btm (ftKB) 9,905.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1B-10 Annotation End DateH2S (ppm) 40 Date 8/12/2016 Comment Mandrels Station No/SPM Top (ftKB) Top Incl (°) Item Des OD Nominal (in) Nominal ID (in) Make Model Top (TVD) (ftKB) 1 2,859.1 47.15 GAS LIFT 5.968 2.915 Camco MMG 2,509.8 2 5,127.3 57.06 GAS LIFT 5.968 2.915 Camco MMG 3,810.4 3 6,733.2 53.33 GAS LIFT 5.968 2.915 Camco MMG 4,654.6 4 7,645.5 34.06 GAS LIFT 5.968 2.915 Camco MMG 5,342.0 5 8,401.1 29.66 GAS LIFT 5.968 2.915 Camco MMG 5,983.1 1B-10L1PB1, 11/8/2021 1:27:23 PM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 Production Casing Cement; 8,870.0 ftKB APERF; 8,959.0-8,979.0 PACKER; 8,922.3 Production Casing Cement; 8,925.0 ftKB Cement Squeeze; 8,901.0 ftKB SLIDING SLEEVE; 8,909.6 Cement Squeeze; 8,894.0 ftKB Cement Retainer; 8,904.0 Cement Squeeze; 8,904.0 ftKB CHEM CUT; 8,901.0 NIPPLE; 8,894.5 X-LOCK; 8,894.0 CEMENT RETAINER (ME); 8,891.0 X-LOCK W/ FLOW THRU SUB; 8,875.0 NIPPLE; 8,875.0 WHIPSTOCK; 8,863.0 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 FISH; 8,795.0 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10L1PB1 ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI Wellbore Status Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE1B-10 Annotation End DateH2S (ppm) 40 Date 8/12/2016 Comment Page 1/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/1/2021 00:00 10/1/2021 02:00 2.00 MIRU, MOVE MOB P Spot rig over well, set down and burrem around the rig and sub. Set down stair ways/hand rails. Unhook jeeps and sows. 0.0 0.0 10/1/2021 02:00 10/1/2021 04:00 2.00 MIRU, MOVE NUND P N/U BOP stack to wellhead 0.0 0.0 10/1/2021 04:00 10/1/2021 06:00 2.00 MIRU, MOVE CTOP P Prep rig and reel stand area for installation of reel. R/U tiger tank and hard line from Wellhead. Hook up hard line from innerconnect areas. 0.0 0.0 10/1/2021 06:00 10/1/2021 10:30 4.50 MIRU, MOVE CTOP P New reel arrived on location. PJSM - installing of new reel into Sub. Install reel Shims and torque bolts as per specs. Continue R/U hard line to TT. 0.0 0.0 10/1/2021 10:30 10/1/2021 19:30 9.00 SLOT, WELLPR CTOP P *** Rig on Hi-line power** Continue with reel installation and M/U iron inside the reel. and position for electrician to install bulkhead 0.0 0.0 10/1/2021 19:30 10/1/2021 22:30 3.00 SLOT, WELLPR CTOP P Prep for stabbing pipe, remove seam from pipe, install sheave on skate hook stabbing cable to tugger 0.0 0.0 10/1/2021 22:30 10/2/2021 00:00 1.50 SLOT, WELLPR CTOP P Electrician install 10k pressure bulkhead 0.0 0.0 10/2/2021 00:00 10/2/2021 03:00 3.00 SLOT, WELLPR CTOP P Electrician install 10k pressure bulkhead 0.0 0.0 10/2/2021 03:00 10/2/2021 05:00 2.00 SLOT, WELLPR CTOP P Make up stabbing cable and stab coil into injector 0.0 0.0 10/2/2021 05:00 10/2/2021 09:30 4.50 SLOT, WELLPR CTOP P Test Mig in cable - good test Install CT connector 0.0 0.0 10/2/2021 09:30 10/2/2021 15:00 5.50 MIRU, WHDBOP CTOP P Pull test - fill coil with 80 degree fresh water. Pressure test conector 5000 psi - pull test 40K Pump slack forward @ 2 bpm for 30 mins. 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 2/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/2/2021 15:00 10/3/2021 00:00 9.00 MIRU, WHDBOP BOPE P BOP test wintessed by Brian Bixby 250/5000 psi Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT Fail / Pass B6, B7, B8, Grease and re- test Fail / Pass 2-3/8" Pipe slip rams equalizer 0.0 0.0 10/3/2021 00:00 10/3/2021 01:00 1.00 MIRU, WHDBOP BOPE P BOP test wintessed by Brian Bixby 250/5000 psi Test 1. Swab 2 Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT Fail / Pass B6, B7, B8, Grease and re- test Fail / Pass 2-3/8" Pipe slip rams equalizer 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 3/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/3/2021 01:00 10/3/2021 03:00 2.00 MIRU, WHDBOP BOPE T Fail / Pass B6, B7, B8, Grease and re- test Fail / Pass 2-3/8" Pipe slip rams equalizer 0.0 0.0 10/3/2021 03:00 10/3/2021 06:00 3.00 PROD1, WHPST PRTS P Pressure test both PDL's & Tiger tank line. 0.0 0.0 10/3/2021 06:00 10/3/2021 08:30 2.50 PROD1, WHPST PULD P Perform Valve checklist. Install injector and reel counters PJSM - P/U clean out BHA 0.0 0.0 10/3/2021 08:30 10/3/2021 09:00 0.50 PROD1, WHPST CTOP P Open Tree/ Pump open SSV - install fusable cap. WH = 125 psi IA = 63 psi OA = 201 psi 0.0 0.0 10/3/2021 09:00 10/3/2021 11:00 2.00 PROD1, WHPST TRIP P RIH while pumping min rate . 3 bpm. 0.0 8,000.0 10/3/2021 11:00 10/3/2021 11:30 0.50 PROD1, WHPST CTOP P Stop and adjust gooseneck 8,000.0 8,000.0 10/3/2021 11:30 10/3/2021 12:00 0.50 PROD1, WHPST TRIP P Continue TIH with 2" coil 8,000.0 8,000.0 10/3/2021 12:00 10/3/2021 13:00 1.00 PROD1, WHPST CIRC P Circulate 1.5 X B/U monitor well for losses 1:1 returns - hole stayed full/static 8,000.0 8,000.0 10/3/2021 13:00 10/3/2021 15:00 2.00 PROD1, WHPST TRIP P TOOH with Clean out BHA from 8,000 ft. Tag up gently at surface Counters less then 1 ft off at surface. 8,000.0 90.0 10/3/2021 15:00 10/3/2021 16:00 1.00 PROD1, WHPST PULD P PJSM - Break off injector & P/U Milling BHA and load into injector 90.0 0.0 10/3/2021 16:00 10/3/2021 19:30 3.50 PROD1, WHPST PULD P Pick up 2-3/8" Northern Solutions motor w/ 2.80 Northern Solutions DSM (SN 9b11195) and Northern Solutions 2.79"ng String Reamer (SN 9b11197) Pressure Deploy BHA, replace packoffs 0.0 90.0 10/3/2021 19:30 10/3/2021 20:30 1.00 PROD1, WHPST TRIP P RIH w/ window mill assembly 100 fpm @ 1 bpm pump pressure 1000 psi , hold 1 for 1 returns 90.0 8,736.0 10/3/2021 20:30 10/3/2021 21:30 1.00 PROD1, WHPST TRIP T Encoder for reel side motor became disconnected and had to be replaced by electrician 8,736.0 8,736.0 10/3/2021 21:30 10/3/2021 23:45 2.25 PROD1, WHPST TRIP P RIH w/ window mill assembly 100 fpm @ 1 bpm pump pressure 1000 psi , hold 1 for 1 returns, Start Duo Vis down coil to be @ bit at top of whip stock , Tie in K1 @ 8671, Log F/ 8660 @ 5 fpm -19.5' Correction, RIH T/ 8820 to circulate Duo Vis from bit to surface 8,736.0 8,822.0 10/3/2021 23:45 10/4/2021 00:00 0.25 PROD1, WHPST CIRC P Circulat Duo Vis F/ Bit @ 8820 to surface 8,822.0 8,822.0 10/4/2021 00:00 10/4/2021 00:15 0.25 PROD1, WHPST CIRC P Circulat Duo Vis F/ Bit @ 8820 to surface 8,822.0 8,845.0 10/4/2021 00:15 10/4/2021 06:00 5.75 PROD1, WHPST MILL P Close EDC, RIH and dry tag WS @ 8846', P/U wt 34k, Pump @ 1.8 bpm 3855psi 670 diff Free spin, Start Milling @ 8845 @ 1fph 8,845.0 8,851.0 10/4/2021 06:00 10/4/2021 06:30 0.50 PROD1, WHPST MILL P Motor stall, 100% losses when first exited casing. P/U 25 ft, circ @ 1.8 BPM, slowly getting some returns back. TIH slowly 8,851.0 8,851.0 10/4/2021 06:30 10/4/2021 19:30 13.00 PROD1, WHPST MILL P Start milling 1.8 BPM, returns .5 bpm, 4041 psi, 545 psi diff pressure, WOB 2.81, MW in 8.55#, CT weight 12.6K, milling 1fph. 8,851.0 8,865.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 4/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/4/2021 19:30 10/4/2021 19:51 0.35 PROD1, WHPST REAM P Ream window F/8840 to various depths as to not create ledge, Down passes as milled ( 1deg LOHS ) up passes 30L, 30R, and 180 R of drilled @ 1 fpm. 1.8bpm , returns 1.03 bpm 3567psi 763 diff MW 8.59 in / 8.67 out PU wt 32k 8,865.0 8,865.0 10/4/2021 19:51 10/4/2021 21:03 1.20 PROD1, WHPST CTOP T 1 pass up at as drilled tool face, on first pass down @ as drilled bit became stuck, worked pipe -12 to 3 down hole weight on bit, pushed 12 k wob and pumped 2bpm came free 8,865.0 8,865.0 10/4/2021 21:03 10/4/2021 22:03 1.00 PROD1, WHPST CIRC T Pump 100 k lsrv pill to bit and squeeze 15 bbls into window track and OH 8,865.0 8,865.0 10/4/2021 22:03 10/4/2021 23:45 1.70 PROD1, WHPST TRIP T POOH laying in remaining 25bbls of 100K LSRV pill, PU WT 34K , open edc POOH @ 107 FPM Pump rate In 1.2 / Out .61 BPM ~ .2 bpm seepage , @ surface holding 100 psi whp 8,865.0 8,865.0 10/4/2021 23:45 10/5/2021 00:00 0.25 PROD1, WHPST PULD T PJSM for Pressure undeploy , tag up at surface space out 1.2 ft Pressure undeploy BHA #2 window mill assembly 8,865.0 8,865.0 10/5/2021 00:00 10/5/2021 01:10 1.17 PROD1, WHPST PULD T Pressure Undeploy BHA# 2 window mill assembly 8,865.0 8,865.0 10/5/2021 01:10 10/5/2021 01:30 0.33 PROD1, WHPST PULD T Lay down , 10' Pup Jt , DSM 2.80 ng, String Reamer 2.79 ng, check Northern Solutions motor, all checked good decision made to re-run motor 8,865.0 8,865.0 10/5/2021 01:30 10/5/2021 02:00 0.50 PROD1, WHPST PULD T Pick up 2.79 ng Crayola mill SN# 0A7812 , Northern Solutions .4 deg AKO motor 8,865.0 8,865.0 10/5/2021 02:00 10/5/2021 03:00 1.00 PROD1, WHPST PULD T Pressure Deploy BHA# 3 Crayola window dressing assembly 8,865.0 8,865.0 10/5/2021 03:00 10/5/2021 05:00 2.00 PROD1, WHPST TRIP T RIH with BHA#3 crayola mill assembly, rih @ 100fpm pump .5 bpm with .5 bpm returns ~ .3 bpm loss rate , Tie in @ 8660 @ 5fpm for -23' correction , close edc run in hole to 8840 8,865.0 8,865.0 10/5/2021 05:00 10/5/2021 10:30 5.50 PROD1, WHPST MILL T Start dressing window 1.80 bpm, returns 1.2 bpm, MW in 8.6, MW out 8.68, Circ pressure 3432psi, WOB .1, CT weight 32K, Made roughly 20 passes reaming crayola mill up/down rolling TF 30 L/30 R/180 HS seeing light motor work @ 8855-8856' until it cleaned up. Cleaned out rathole down to 8865' 8,865.0 8,865.0 10/5/2021 10:30 10/5/2021 11:30 1.00 PROD1, WHPST MILL T While rotating 180 LS saw overpull @ TOW 8845' - motor stall. Mill was stuck but motor could still orientate freely. Work string Max overpull up 9K, Max down 10K, worked free. P/U and circulate hole clean 8,865.0 8,865.0 10/5/2021 11:30 10/5/2021 12:00 0.50 PROD1, WHPST CIRC T While circulating B/U moving BHA above window Pull tight into landing nipple @ 8835' - Drop down, made multiple attempts dry/ pumping. no luck. While pumping in free spin area, the motor stalled indicating we have some junk beside or around the Bit. Rotated 180 LS and pulled through nipple @ 8835' - continue TOOH with 3K drag on BHA. 8,865.0 8,865.0 10/5/2021 12:00 10/5/2021 14:30 2.50 PROD1, WHPST TRIP T TOOH @ 50 fpm to surface to inspect BHA. 8,865.0 90.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 5/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/5/2021 14:30 10/5/2021 17:00 2.50 PROD1, WHPST PULD T CT @ surface PJSM - Pressure Undeploy BHA #3 - window dressing assembly. Large chunk( 1.5" - 2") of crayola mill had broken off and remained in hole. 90.0 0.0 10/5/2021 17:00 10/5/2021 19:00 2.00 PROD1, WHPST WAIT T Wait on slickline unit. 90.0 0.0 10/5/2021 19:00 10/5/2021 19:30 0.50 PROD1, WHPST SLKL T Slick line crew on location, PJSM, spot truck and offload lubricator to pipe shed. 90.0 0.0 10/5/2021 19:30 10/6/2021 00:00 4.50 PROD1, WHPST SLKL T PJSM on RU, RU slick line PCE and tool string - 2.84" gauge ring. 0.0 0.0 10/6/2021 00:00 10/6/2021 02:00 2.00 PROD1, WHPST SLKL T RIH with slick line, 2.84" gauge ring. Crew change out @ 01:30. Drift to X nipple @ 8,832'. POOH 0.0 0.0 10/6/2021 02:00 10/6/2021 05:00 3.00 PROD1, WHPST SLKL T RD drift tool string, RU flow through X lock, RIH. Hang up temporarily at he SSSV hand spang through, continue in hole, Set X lock @ 8,832'. 0.0 0.0 10/6/2021 05:00 10/6/2021 07:00 2.00 PROD1, WHPST SLKL T RIH with slick line check set. Sheared indicator pin, Good run. 0.0 0.0 10/6/2021 07:00 10/6/2021 09:00 2.00 PROD1, WHPST SLKL T R/D slickliine 0.0 0.0 10/6/2021 09:00 10/6/2021 11:15 2.25 PROD1, WHPST PULD T PJSM - P/U and deploy Whipstock BHA 0.0 74.0 10/6/2021 11:15 10/6/2021 13:27 2.20 PROD1, WHPST TRIP T TIH with BHA #4, Whipstock assembly. Slowing speed through jewelry sections in the well. 74.0 8,660.0 10/6/2021 13:27 10/6/2021 13:45 0.30 PROD1, WHPST DLOG T Tie into K1 for -22.5' correction. P/U weight 35k. 8,660.0 8,735.8 10/6/2021 13:45 10/6/2021 14:03 0.30 PROD1, WHPST TRIP T Continue in hole, tag X nipple @ 8834' - TOWS - 8821.88' - Set 0 degree HS. Closed ECD slowly pressured up 1500, 2000, 3000 psi set WS @ 3000 psi, pressure drop occurred, pumped additional 3 bbls to ensure it was set. P/U weight 35K 8,735.8 8,810.0 10/6/2021 14:03 10/6/2021 14:45 0.70 PROD1, WHPST DISP T Squeezed 30 bbls of 100K LSRV pill, lay in 10 bbls on top. 8,810.0 8,810.0 10/6/2021 14:45 10/6/2021 16:21 1.60 PROD1, WHPST TRIP T POOH 8,810.0 47.0 10/6/2021 16:21 10/6/2021 18:21 2.00 PROD1, WHPST PULD T Tag up, Space out, PUD BHA #4, whipstock running BHA. 47.0 0.0 10/6/2021 18:21 10/6/2021 18:51 0.50 PROD1, WHPST CTOP T Covid testing of all - All negative. 0.0 0.0 10/6/2021 18:51 10/6/2021 20:21 1.50 PROD1, WHPST PULD T PU and PD BHA #5 - Whipstock milling assembly. IA 113 psi, OA 239 psi 0.0 75.0 10/6/2021 20:21 10/6/2021 22:15 1.90 PROD1, WHPST TRIP T Bump up, set counters, RIH with BHA #5- Window milling assembly. String reamer and diamond mill both 2.80 No Go. Start displacing ~40 bbl 100k Cp Hi vis pill. 75.0 8,660.0 10/6/2021 22:15 10/6/2021 22:51 0.60 PROD1, WHPST DLOG T Tie into the K1. Lost counter signal temporarily, Picked up, counters returned, RBIH to complete tie in for - 23' correction. 8,660.0 8,750.0 10/6/2021 22:51 10/6/2021 23:09 0.30 PROD1, WHPST SVRG T Inspect and tighten inner reel iron. 8,750.0 8,727.0 10/6/2021 23:09 10/7/2021 00:00 0.85 PROD1, WHPST DISP T Squeeze high vis pill away. 1.80 bpm in, 1.25 bpm out, CT 3135 psi, BHP 3335 psi, WH 0 psi. IA 170 psi, OA 545 psi 8,727.0 8,727.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 6/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/7/2021 00:00 10/7/2021 00:36 0.60 PROD1, WHPST TRIP T Close EDC, PU Wt 32 k lbs, RIH Wt 17 k lbs, pumps off, dry tag TOWS @ 8822' 8,727.0 8,822.0 10/7/2021 00:36 10/7/2021 03:00 2.40 PROD1, WHPST WPST T PU and set rate @ 1.78 bpm in, 1.25 bpm out, CT 3500 psi, BHP 3368 psi. Free spin diff 500 psi. RIH and mill exit window. CT wt 11.38 k lbs, WOB 2 k lbs, one stall on first tag at rate, P clean and restart. mill exit window w ~ 125 psi motor work. ROP 0.8 ft/hr 8,822.0 8,823.8 10/7/2021 03:00 10/7/2021 15:00 12.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3627 psi, BHP 3364 psi, @ 1.79 bpm in and 1.26 bpm out. Ct Wt 11.4 k lbs, WOB 2.17 k lbs, ROP 0.8 ft/hr. 8,823.8 8,827.9 10/7/2021 15:00 10/7/2021 18:00 3.00 PROD1, WHPST WPST T Milling, CT 4'129 psi, BHP 3,369 psi, @ 1.77 bpm in and 1.36 bpm out. Ct Wt 10.9 k lbs, WOB 3.26 k lbs 8,827.9 8,828.8 10/7/2021 18:00 10/7/2021 21:00 3.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 4,031 psi, BHP 3,398 psi, @ 1.78 bpm in and 1.35 bpm out. Ct Wt 10.3 k lbs, WOB 3.4 k lbs. **Bleed OA from 977 psi to 600 psi. Mostly gas. IA 414 psi 8,828.8 8,830.0 10/7/2021 21:00 10/8/2021 00:00 3.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3,835 psi, BHP 3,387 psi, @ 1.79 bpm in and 1.39 bpm out. Ct Wt 10.64 k lbs, WOB 3.8 k lbs 8,830.0 8,831.0 10/8/2021 00:00 10/8/2021 03:00 3.00 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3,835 psi, BHP 3,387 psi, @ 1.79 bpm in and 1.39 bpm out. Ct Wt 10.64 k lbs, WOB 3.8 k lbs 8,831.0 8,831.5 10/8/2021 03:00 10/8/2021 08:54 5.90 PROD1, WHPST WPST T Milling 2.80" exit window. CT 3,778 psi, BHP 3,401 psi, @ 1.79 bpm in and 1.39 bpm out. Ct Wt 10.57 k lbs, WOB 3.8 k lbs Penetrated 9-5/8" at 8832, returns fell from 1.4 to 1.1 and healed to 1.2 bpm. **suction pit foamed up @ 0410 Time mill @ 1'/hr to 8833.2 Mill rat hole to 8847' 8,831.5 8,847.0 10/8/2021 08:54 10/8/2021 10:30 1.60 PROD1, WHPST REAM P Ream window @ 1'/min , 3 passes @ HS, 1 pass ea. @ 30L , 30R, and 180, Pump rate 1.78 bpm 3748 psi 512 diff , pu wt 35 8,847.0 8,847.0 10/8/2021 10:30 10/8/2021 11:18 0.80 PROD1, WHPST CIRC P Circulate sweeps 5 bbl lowvis followed by 5 bbls high vis 8,847.0 8,847.0 10/8/2021 11:18 10/8/2021 13:30 2.20 PROD1, WHPST TRIP P Open EDC , POOH 100 fpm pumping 2 bpm with 1.33 bpm returns, ~.3 bpm seepage , pump pressure 3525 psi , perform jog @ 500' ran in hole @ 100 fpm T/1147, POOH tag up @ surface 8,847.0 8,847.0 10/8/2021 13:30 10/8/2021 15:00 1.50 PROD1, WHPST PULD P PJSM , space out tool, pressure undeploy BHA# 5 window mill assembly and lay down tools 8,847.0 8,847.0 10/8/2021 15:00 10/8/2021 15:18 0.30 PROD1, DRILL PULD P Pick up bha # 6- 2.5 deg AKO w/ BH Talon Bit 8,847.0 8,847.0 10/8/2021 15:18 10/8/2021 16:33 1.25 PROD1, DRILL PULD P Pressure Deploy BHA# 6 - Build drilling assembly, surface pressure 470psi 8,847.0 8,847.0 10/8/2021 16:33 10/8/2021 18:15 1.70 PROD1, DRILL TRIP P Tag up set depth 72.21 for bha#6 , RIH @ 100 fpm .35 bpm 8,847.0 8,847.0 10/8/2021 18:15 10/8/2021 18:33 0.30 PROD1, DRILL DLOG P Tie into the K1 for - 22.5' correctio 8,847.0 8,847.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 7/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/8/2021 18:33 10/8/2021 18:57 0.40 PROD1, DRILL TRIP P Continue in hole, park and close EDC, PU Wt 32 k lbs, RIH though window clean. Slight WOB bobble and CT wt bobble at 3 foot below the window ( 8835') continue in hole 8,847.0 8,847.0 10/8/2021 18:57 10/8/2021 20:00 1.05 PROD1, DRILL DRLG P Drill L1 buid turn, CT 3,949 psi @ 1.80 bpm in and 1.40 bpm out. CT Wt 10.9 k lbs, 3 k WOB. 8,847.0 8,906.0 10/8/2021 20:00 10/9/2021 00:00 4.00 PROD1, DRILL DRLG P Drill L1 buid turn, CT 3,960 psi @ 1.80 bpm in and 1.46 bpm out. CT Wt 11.4 k lbs, 3 k WOB. 8,906.0 8,976.0 10/9/2021 00:00 10/9/2021 06:30 6.50 PROD1, DRILL DRLG P Drill L1 build turn, CT 4128 psi @ 1.80 bpm in and 1.51 bpm out. CT Wt 10.6 k lbs, 1.5 - 3 k WOB. Free spin diff 500 psi. 8,976.0 9,220.0 10/9/2021 06:30 10/9/2021 09:00 2.50 PROD1, DRILL TRIP P POOH @ 50'/min to window , Open EDC @ 8790' , POOH @ 100'/min 2.24 bpm 4120 psi 9,220.0 78.0 10/9/2021 09:00 10/9/2021 10:30 1.50 PROD1, DRILL PULD P PJSM, Tag up and space out 1.2' , Pressure Un-deploy BHA # 6 Build Assembly 550 psi surface pressure 78.0 0.0 10/9/2021 10:30 10/9/2021 11:00 0.50 PROD1, DRILL BOPE P Vacuume out stack and function test bop's 0.0 0.0 10/9/2021 11:00 10/9/2021 12:30 1.50 PROD1, DRILL PULD P Pick up xtreme .5 AKO motor with Hycalog SR3211-A3 SN# A257637 , Deploy BHA # 7 Lateral Drilling Assembly , change packoffs 0.0 78.0 10/9/2021 12:30 10/9/2021 15:00 2.50 PROD1, DRILL TRIP P Tag up set depth, RIH 100 fpm .4 bpm ,Close EDC @ 500' shallow agitator test 1.8 bpm 4520 psi 1045 diff , Tie in @ 8680 5 fpm for -24.5' Correction, 78.0 9,224.0 10/9/2021 15:00 10/9/2021 17:54 2.90 PROD1, DRILL DRLG P Tag bottom @ 9224' , begin drilling , 1.85 bpm in 1.36 bpm out 4760 psi , up wt 36 K coil wt while drilling 9.4 K 1.25 WOB ROP 200'/hr pulling bha wiper every 100' due to low out rate 9,224.0 9,620.0 10/9/2021 17:54 10/9/2021 18:06 0.20 PROD1, DRILL WPRT P PUH on wiper trip. PU Wt 37 k lbs. 9,620.0 9,248.0 10/9/2021 18:06 10/9/2021 18:18 0.20 PROD1, DRILL WPRT P RBIH 9,248.0 9,620.0 10/9/2021 18:18 10/9/2021 22:24 4.10 PROD1, DRILL DRLG P BOBD- CT 4560 psi, BH 3571 psi, @ 1.8 bpm in and 1.40 bpm out. Free spin diff 1120 psi. BHA kicked from 93° to 89.5° @ 9680' ROP fell from 200 ft/hr to sub 100 ft/h ~ 9678' PU Wt 42 k lbs @ 9691' PU Wt 55 k lbs @ 9693' - drilling something different, ratty, stacking weight. Kicked down again @ 9780' from 91.5° to 89° @ 9821' dropped pump rate to 1.6 bpm, targeted 3.5 k WOB, skidded along hard layer then kicked down to 83° @ 9884' Drilling low res rock at high ROP, unable to break through hard layer ~ C3 /C4 interface. Geo reports flakes of siderite in cuttings. 9,620.0 9,905.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 8/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/9/2021 22:24 10/10/2021 00:00 1.60 PROD1, DRILL TRIP P POOH for larger bend motor. PU Wt 34 k lbs Open hole clean. Slight 0.8 k lbs WOB tug at 8824.5' Open EDC, Continue to POOH 2.12 bpm in and 1.45 bpm out. 9,905.0 3,713.0 10/10/2021 00:00 10/10/2021 01:00 1.00 PROD1, DRILL TRIP P Continue to POOH, CT Wt 14 k lbs 2.12 bpm in and 1.59 bpm out. 3,713.0 78.0 10/10/2021 01:00 10/10/2021 02:30 1.50 PROD1, DRILL PULD P Bump up & space out. PUD BHA #7, lat drilling assembly w 0.5° AKO moor and Hyc A3 bit. 78.0 0.0 10/10/2021 02:30 10/10/2021 04:06 1.60 PROD1, DRILL PULD P PU and PD BHA #8, L1 lateral drilling assembly - second try. 0.0 78.0 10/10/2021 04:06 10/10/2021 04:30 0.40 PROD1, DRILL TRIP P Bump up, set counters, RIH with BHA #8, NOV agitator, 0.8° AKO motor with BH Dynamus bit. 78.0 1,595.0 10/10/2021 04:30 10/10/2021 10:30 6.00 PROD1, DRILL SVRG T Injector stopped @ 1595' Troubleshoot issue. 1,595.0 1,595.0 10/10/2021 10:30 10/10/2021 12:00 1.50 PROD1, DRILL TRIP P Shallow agitator test 1.8 bpm , 915 dif 4275 pp , RIH @ 100 fpm , .25 bpm , tie in @ 8680' for -25' correction , started mud swap from duovis to power pro , PU wt 35 K SO wt 15 k RIH to 8820 1,595.0 8,820.0 10/10/2021 12:00 10/10/2021 12:30 0.50 PROD1, DRILL TRIP T Set down in window @ 8825' , pu wt 45 K to 8790' dragging junk pump 1 bpm motor stalled , broke free 8,820.0 8,790.0 10/10/2021 12:30 10/10/2021 13:15 0.75 PROD1, DRILL CIRC T Circulate Power Pro to bit for mud swap 9 bbls in pipe when hung up decision was made to finish with fluid swap prior to trip out 8,790.0 8,790.0 10/10/2021 13:15 10/10/2021 14:45 1.50 PROD1, DRILL TRIP T POOH EDC open pump 2.4 in pump pressure 3850 psi , trip out for D331 clean out bha 8,790.0 72.6 10/10/2021 14:45 10/10/2021 16:00 1.25 PROD1, DRILL PULD T PJSM , tag up space out 1.2' , Pressure undeploy BHA# 8 Lateral drilling assembly .7 AKO motor 545 psi surface pressure 72.6 0.0 10/10/2021 16:00 10/10/2021 16:12 0.20 PROD1, DRILL PULD T Reconfigure BHA, drop ultra slim resistivity for clean out run. 0.0 0.0 10/10/2021 16:12 10/10/2021 17:24 1.20 PROD1, DRILL PULD T PU/ PD BHA #9, clean out run with 0.6° AKO motor and D331 ridge set bit. ** 2.79" no Go 0.0 62.0 10/10/2021 17:24 10/10/2021 18:36 1.20 PROD1, DRILL TRIP T RIH W BHA #8, 62.0 8,660.0 10/10/2021 18:36 10/10/2021 19:00 0.40 PROD1, DRILL TRIP T Tie into the K1 for -26' correction. Close EDC, 8,660.0 8,717.0 10/10/2021 19:00 10/10/2021 20:00 1.00 PROD1, DRILL SVRG T Service rig, lock out reel and tighten leaking inner reel iron - took two attempts 8,717.0 8,717.0 10/10/2021 20:00 10/10/2021 21:54 1.90 PROD1, DRILL WASH T PU W 38 k lbs, RIH, 8801, stack weight and pressure up, stall. PU clean @ 35 k lbs. RBIH and stacked 2.3 k WOB, hard stall with heavy reactive torque. PU Wt 40 k lbs saw -4.5 k WOB then drug -2.6 k WOB till popped free. Chase 10 bbl High Vis surface to surface, pristine returns. RBIH, cut pump rate to min ~.4 bpm Clean to stack out with 4 k lbs WOB just above window at 8820'. PU Wt 45 k bs, -4 k WOB. Pressured up, stalled. PUH dragging junk. Work pipe up and down, rotate HOT left right, some amping up but mostly free, work pump to .7 bpm and 1000 psi diff. 8,717.0 8,455.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 9/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/10/2021 21:54 10/10/2021 22:36 0.70 PROD1, DRILL TRIP T Pull heavy at Seal bore assembly, CT Wt 50 k lbs, -14.9 k WOB. Work pipe, down weight 10 k lbs up weight -17 k WOB. Pump down the back side, ( WH 1418, 1.69 bpm, BHP 3470 psi, ECD 11.2 ppg), rotate HOT, work pipe. Pop free. 8,455.0 8,455.0 10/10/2021 22:36 10/11/2021 00:00 1.40 PROD1, DRILL TRIP T PUH while pumping 5 bbls down back side. Consult with town engineering. Line up down the coil build 50 bbl Hi vis sweep while continuing to pull slowly up hole. IA = 184 psi and OA = 541 psi 8,455.0 8,190.0 10/11/2021 00:00 10/11/2021 02:12 2.20 PROD1, DRILL DISP T RIH to 8400' and lay in 46 bbls of high vis pill while pulling up hole. Park and line up down the back side. Bullhead hi vis sweep to the formation at 2.3 bpm, WH 1399, ECD 15 ppg. Slowly RIH while bullheading. 8,190.0 4,615.0 10/11/2021 02:12 10/11/2021 03:12 1.00 PROD1, DRILL WASH T Swap back to pumping down the coil. trip in hole. Set rate @ 8400', CT RIH Wt 13 k lbs, CT 3,442 psi At 1.88 bpm in and 1.56 bpm out. Free spin diff 431 psi. SBE area clean, 4,615.0 8,860.0 10/11/2021 03:12 10/11/2021 03:24 0.20 PROD1, DRILL DLOG T Tie into the K1 for +7' correction PU Wt 31 k lbs. 8,860.0 8,708.0 10/11/2021 03:24 10/11/2021 03:30 0.10 PROD1, DRILL WASH T Continue to RIH. CT Wt 14 k lbs, CT 3448 psi @ 1.88 bpm in and 1.61 bpm out. BHP 3408 psi, free spin diff 425 psi. 10.48 ECD at the window. 8,708.0 8,822.9 10/11/2021 03:30 10/11/2021 04:18 0.80 PROD1, DRILL WASH T Set down in the window @ 8822.87. WOB to 3.39 k lbs, stall. PU Wt 35 k lbs, clean. Restart, drop RIH speed through window from 5 ft/min to 1 ft/min stall. again at 0.3 ft/min stall 33 k PU Wt - clean Sneak up on it and set auto driller at 3' per hr, saw motor work 8822.39' burn off, stack and stall @ 8822.43', reset, same effect stall at 8822.4' PU 35 k lbs, clean, pumps to min rate, RIH, stack out 3.4 k WOB at 8822.3' PU 32 k lbs, clean. 8,822.9 8,822.9 10/11/2021 04:18 10/11/2021 06:18 2.00 PROD1, DRILL TRIP T POOH with BHA #9. Puming 1.88 bpm in and 1.54 bpm out, 8,822.9 62.0 10/11/2021 06:18 10/11/2021 07:48 1.50 PROD1, DRILL PULD T PUD BHA # 9 D331 clean out assembly 62.0 0.0 10/11/2021 07:48 10/11/2021 10:33 2.75 PROD1, DRILL WAIT T Waiting for Baker Oil Tools hand with venturi 0.0 0.0 10/11/2021 10:33 10/11/2021 12:33 2.00 PROD1, DRILL PULD T Pick up Baker Oil Tools Venturi and UP/ Down Jars , High side tool with scoup facing up, Pressure Deploy BHA# 10 venturi run 0.0 0.0 10/11/2021 12:33 10/11/2021 14:27 1.90 PROD1, DRILL TRIP T Tag up @ surface, set depths 66.41' , RIH with BHA# 10 venturi assembly , 100 fpm EDC open pump .34 bpm , Tie in @ 8680' for -25' correction RIH to 8800' Close EDC PU wt 34 k 0.0 8,800.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 10/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/11/2021 14:27 10/11/2021 15:21 0.90 PROD1, DRILL FISH T Close EDC , pump 2 bpm , Wash down with venturi@ 2'/min F/8800 T/ 8821.95 tagged fish W/ 1.8 wob circulated on fish 1 min , picked up 34K to 8815, Wash down with Scoup down F/ 8815 T/88821.17 w/ .3 wob , PU T/8815 31 k - 1.2 WOB , Turn veturi scoup up, Wash down F/ 8815 T/8821.17 @ 1 fpm set down .46 wob , torque in with tool pu 31 k orient 90 R wash F/ 8815 T/ 8821.17 sat down .91 wob orient 180 R WOB fell to .4 , RIH T/8821.33 1.08 WOB Orient back to 90R tool torqued up, PU T/ 8813 Wash down F/8813 T/8821.17 set down .86 wob , P/U T 8812 RIH to 8821.53 set down 2.5 wob , P/U to 8812 RIH 90 L T/ 8821.29 Set Down 1.8 wob, torque L pick up T/8813 orient HS, RIH T/8821.35 set down, PU T/ 8813.57 orient low side RIH T/ 8821 WHP 175psi dump choke RIH T/8820.89 .51 wob 8,800.0 8,821.0 10/11/2021 15:21 10/11/2021 17:21 2.00 PROD1, DRILL TRIP T Paint yellow flag - POOH w/ BHA # 10 straight venturi assembly 8,821.0 0.0 10/11/2021 17:21 10/11/2021 19:21 2.00 PROD1, DRILL PULD T PJSM , PUD BHA# 10 service break venturi tool and install nozzle on end of coil 0.0 0.0 10/11/2021 19:21 10/11/2021 19:57 0.60 PROD1, DRILL CIRC T Circulate coil over to clean water 0.0 0.0 10/11/2021 19:57 10/11/2021 20:42 0.75 PROD1, DRILL CIRC T Pump 80 bbls clean water down well @ 2.5bpm clear well bore of power pro 0.0 0.0 10/11/2021 20:42 10/11/2021 21:30 0.80 PROD1, DRILL PULD T Pop injector off well and pick up camera bha , test cameral @ Surface max od on sleeve 2.375" 0.0 16.0 10/11/2021 21:30 10/12/2021 00:00 2.50 PROD1, DRILL TRIP T Tag up, set depth, RIH @ 80'/min pump min rate @ 7000' fill coil w/ methanol from little red , pump 1.5 bpm 16.0 8,473.0 10/12/2021 00:00 10/12/2021 03:00 3.00 PROD1, DRILL DLOG T Continue in hole with camera. Line up down the coil with neat MetOH. RIH to painted flag depth from previous BHA ~ 46' foot from TOWS. Pump MetOH to the bit while RIH slowly. Clean picture shortly after methanol lake water interface @ 00:04. Run in hole logging live video. 8,473.0 8,473.0 10/12/2021 03:00 10/12/2021 06:00 3.00 PROD1, DRILL TRIP T Pull heavy CT Wt to 42 k @ 8,868'. Unable to RBIH stacking neutral weight, unable to PUH pulling in steps to 40 k over, Clean pick up weight 35 k lbs. Line up down the back side and pump to 2 bpm, while working pipe. Turn coil and well over to PowerPro drilling mud. Work pipe from 80 k CT Wt to -9 k CT wt. - crew change 8,868.0 8,868.0 10/12/2021 06:00 10/12/2021 09:00 3.00 PROD1, DRILL TRIP T Work pipe from 80 k to -10 k lbs. Inspect injector, pump up tractions circuit. Displace well to power pro, release EVO camera. Release BOT. Work pipe from 80 k to -10 k lbs. load 7 bbls LVT into pill pit, pump around coil. 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 11/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/12/2021 09:00 10/12/2021 12:00 3.00 PROD1, DRILL TRIP T Let LVT soak 30 minutes. work pipe from 80 k to -10 k lbs. Build 5 bbl beaded pill with active mud and 1 ppb alpine beads, pump down coil and up backside. Work coil from 80 k lbs to -10 k lbs. 8,868.0 8,868.0 10/12/2021 12:00 10/12/2021 15:00 3.00 PROD1, DRILL TRIP T Inspect injector and traction circuits. Work k coil from 100 k lbs max pull to - 10 k lbs. Circulate mud until MW in = MWO at 8.58 ppb. Trap pressure and observe wellhead to determine KW fluid. 8,868.0 8,868.0 10/12/2021 15:00 10/12/2021 16:18 1.30 PROD1, DRILL TRIP T WH fell from 504 to 321 at 16:30. Clean pit1 and pill pit 1 for KW fluid while observing WH. 8,868.0 8,868.0 10/12/2021 16:18 10/12/2021 19:18 3.00 PROD1, DRILL TRIP T WH down to 185 psi, 9.33 ppg static 8,868.0 8,868.0 10/12/2021 19:18 10/12/2021 21:18 2.00 PROD1, DRILL TRIP T PJSM w/ rig crew, work pipe a little, pump down coil keeping coil pressure under 3,000 psi, phone for approval to work pipe -22k continue working pipe w/no movement. 8,868.0 8,868.0 10/12/2021 21:18 10/12/2021 23:18 2.00 PROD1, DRILL TRIP T PJSM w/rig crew, line up to starve rig pump while working pipe between RIHW, PUW, Neutral. 8,868.0 8,868.0 10/12/2021 23:18 10/13/2021 00:00 0.70 PROD1, DRILL TRIP T Park at 25k, discuss plan forward with crew. 8,868.0 8,868.0 10/13/2021 00:00 10/13/2021 00:24 0.40 PROD1, DRILL TRIP T Park in netural weight 8,868.0 8,868.0 10/13/2021 00:24 10/13/2021 02:24 2.00 PROD1, DRILL TRIP T Continue working pipe up to 80k w/no movement. 8,868.0 8,868.0 10/13/2021 02:24 10/13/2021 02:54 0.50 PROD1, DRILL CTOP P WHP 319, 150 psi to 225 psi 80 psi to 215 psi 8,868.0 8,868.0 10/13/2021 02:54 10/13/2021 04:12 1.30 PROD1, DRILL CTOP P Discuss with town team Cut 10.7 ppg to 10.1 ppg 8,868.0 8,868.0 10/13/2021 04:12 10/13/2021 06:00 1.80 PROD1, DRILL DISP P Displace well to 10.1 ppg 8,868.0 8,868.0 10/13/2021 06:00 10/13/2021 07:00 1.00 PROD1, DRILL CIRC P Perform static loss test, 20 minute wait - 0.2 bpm losses Dynamic losses, when pumping over the top with charge pump 0.5 bpm 8,868.0 8,868.0 10/13/2021 07:00 10/13/2021 08:00 1.00 PROD1, DRILL CIRC P Discuss with town team, build 10.1 KW for coil with 776 lube. 8,868.0 8,868.0 10/13/2021 08:00 10/13/2021 08:18 0.30 PROD1, DRILL CIRC P Planns changed during morning meeting. Decision to load well with 9.8 NaCl. Call for brine and truck 8,868.0 8,868.0 10/13/2021 08:18 10/13/2021 14:48 6.50 PROD1, DRILL WAIT P Wait on 9.8 ppg brine 8,868.0 8,868.0 10/13/2021 14:48 10/13/2021 16:36 1.80 PROD1, DRILL DISP P Transfer NaCl brine to pits, verify weight. Bullhead 60 bbls 9.8 ppg NaCl down the annulus. 8,868.0 8,868.0 10/13/2021 16:36 10/13/2021 18:30 1.90 PROD1, DRILL DISP P Wait for slick 9.8 NaCl coil pill to be built. Pump 8,868.0 8,868.0 10/13/2021 18:30 10/13/2021 19:30 1.00 PROD1, DRILL DISP P Displace coil to 9.8 ppg 8,868.0 8,868.0 10/13/2021 19:30 10/13/2021 20:30 1.00 PROD1, DRILL CIRC P Shutdown, open lubricator at surface, shut valve on standing iron, open inner reel bleeder, montior well for flow 8,868.0 8,868.0 10/13/2021 20:30 10/13/2021 21:30 1.00 PROD1, DRILL CIRC P Rig floor on a vacuum, and inner reel slight 1/16" stream, continue to monitor well and coil for flow. 8,868.0 8,868.0 10/13/2021 21:30 10/13/2021 21:45 0.25 PROD1, DRILL CIRC P No flow, obtain static loss rate 4.0 bph 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 12/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/13/2021 21:45 10/13/2021 22:15 0.50 PROD1, DRILL CTOP P PJSM, pull coil in tention 27k (20 %), function closed upper and lower pipe/slip rams, function to high side, manually lock in rams, 8,868.0 8,868.0 10/13/2021 22:15 10/13/2021 22:45 0.50 PROD1, DRILL CTOP P PJSM, strip up INJH, 86" from rig floor, mark pipe, install false bowl, slips, and dog collar, 8,868.0 8,868.0 10/13/2021 22:45 10/14/2021 00:00 1.25 PROD1, DRILL CTOP P PJSM, MU and install HOT TAP, drill hole into coiled tubing, confirm hole in tubing, Coil on Suck 8,868.0 8,868.0 10/14/2021 00:00 10/14/2021 07:00 7.00 PROD1, DRILL CTOP T Standby for Eline crew availablity, filling hole every hour 4 bbls 8,868.0 8,868.0 10/14/2021 07:00 10/14/2021 07:30 0.50 PROD1, DRILL CTOP P Stage scafold material to rig floor. 8,868.0 8,868.0 10/14/2021 07:30 10/14/2021 10:00 2.50 PROD1, DRILL CTOP P Remove hot tap equipment. Cut coil, excess wire pulled easily from upper end of coil. Clamp and cut wire. Skid injector 8,868.0 8,868.0 10/14/2021 10:00 10/14/2021 11:00 1.00 PROD1, DRILL CTOP P Rigged up Tugger and RON weight cell to wire line clamp. Pull~60' to 550 lbs - reset clamp Pull ~60' to 1,500' - reset clamp Pull ~60' to 2,800 lbs - reset clamp Pull ~10' to 2,680 lbs, weight broke back - anchor appeared to break free. 8,868.0 8,868.0 10/14/2021 11:00 10/14/2021 12:00 1.00 PROD1, DRILL CTOP P Pull excess slack to reach e-line ~ 400' total. Scaffold crew erected work platform on rig floor 8,868.0 8,868.0 10/14/2021 12:00 10/14/2021 13:30 1.50 PROD1, DRILL CTOP P RU e-line, Tie knot in wire. 8,868.0 8,868.0 10/14/2021 13:30 10/14/2021 18:00 4.50 PROD1, DRILL CTOP P Pull e-line from coiled tubing string. Atypical wire removal. Dragging something heavy - near surface ~ 2000' weight falling off to zero then dragging 2000 lbs. Stop at 500' use tugger to pull remaining wire Anchor retrieved e-line retrieved 8300' coil crew stripped 500' at surface 8,868.0 8,868.0 10/14/2021 18:00 10/14/2021 18:45 0.75 PROD1, DRILL CTOP P Dress coil stump install BOT External CTC, pull test traveling block hanging weight 14k, pull test to 42k, slack off, retighten, lock-tite set screws, 8,868.0 8,868.0 10/14/2021 18:45 10/14/2021 21:45 3.00 PROD1, DRILL CTOP P RU hose to pump in sub, complete building of 30 bbls lube pill, fill coil with 9.8 kwf (viscosified with 2% concentratrion of Lube 776), Sim-ops, eline mu cutter drift assembly on ground, and bring tools & equipment to RF. 8,868.0 8,868.0 10/14/2021 21:45 10/14/2021 22:15 0.50 PROD1, DRILL ELNE T Unable to RIH w/e-line past +/- 21', POOH, check tools, take picture of sticky tar on bottom of bullnose. 8,868.0 8,868.0 10/14/2021 22:15 10/14/2021 23:15 1.00 PROD1, DRILL ELNE T LD tools, take over to rig shop and dress eline head to 1.4" without burrs 8,868.0 8,868.0 10/14/2021 23:15 10/15/2021 00:00 0.75 PROD1, DRILL ELNE T Load E-line tools up to RF, MU eline rope socket 8,868.0 8,868.0 10/15/2021 00:00 10/15/2021 02:00 2.00 PROD1, DRILL ELNE T Set down w/ E-line drift 2,050' worked to get down to 2,184', over pulling 400lbs, We captured video of sample taken from tool string. E-line head rated for 900 lb. over pull. Decision was made to send E- liners to bed 8 hrs (10am), 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 13/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/15/2021 02:00 10/15/2021 04:00 2.00 PROD1, DRILL ELNE T Send E-liners to bed for 8 hrs (10am), Rooms in Kuparuk KCC, call out additional 1502 parts for rigging up Little Red Services to RF for flushing coiled tubing, work sample in mud lab to determine best course of action with fluids. 8,868.0 8,868.0 10/15/2021 04:00 10/15/2021 07:00 3.00 PROD1, DRILL ELNE T Consult with town engineering, work plan forward. deliver sample of sludge from inside coil to kuparuk lab. 8,868.0 8,868.0 10/15/2021 07:00 10/15/2021 09:00 2.00 PROD1, DRILL WAIT T Wait on LRS 8,868.0 8,868.0 10/15/2021 09:00 10/15/2021 10:00 1.00 PROD1, DRILL ELNE T PJ discussion w LRS and crew. SPot up, rig up LRS build pump in 4 way above external coil connector. Verify CTC pressure limit of 5000 psi. PT both LRS and Nabors line to 3500 psi. 8,868.0 8,868.0 10/15/2021 10:00 10/15/2021 12:00 2.00 PROD1, DRILL ELNE T Wait on brine, Kuparuk lab relied to sample. They tried to dissolve / suspend with methanol, acid, and mutual solvent with no success. Sample simply balled up with none dissolving or going into suspension. Xylene and toluene both dissolved the sample. Stock field corrosion inhibiter partially dissolved the sample. 8,868.0 8,868.0 10/15/2021 12:00 10/15/2021 15:12 3.20 PROD1, DRILL DISP T Truck on location with 9.8 + KW. Verify density and RU to LRS. On line with LRS, Pump 100 bbls of diesel at 130 °F and 1.5 - 1.6 bpm and 2300 psi. Pump 100 bbls of 9.8 + nacl KW brine at 2350 psi and 1.7 to 1.9 bpm. SD, isolate, suck back LRS, release Hot oil. 8,868.0 8,868.0 10/15/2021 15:12 10/15/2021 16:00 0.80 PROD1, DRILL ELNE T Realign valves, verify no flow. Fill coil and backside (11 bbls - 1000' of 4.5" ) for 1 hr flow check. 8,868.0 8,868.0 10/15/2021 16:00 10/15/2021 16:30 0.50 PROD1, DRILL OWFF T Open bleed on coil and back side- observe for flow. 8,868.0 8,868.0 10/15/2021 16:30 10/15/2021 17:30 1.00 PROD1, DRILL OWFF T Attempt to load E line tool into coil. Unable to fall through coil, re position easy torques 8,868.0 8,868.0 10/15/2021 17:30 10/15/2021 20:30 3.00 PROD1, DRILL ELNE P Tools falling in hole freely, continue working to bottom. 8,868.0 8,868.0 10/15/2021 20:30 10/15/2021 20:42 0.20 PROD1, DRILL ELNE P At surface, LD E-line drift, tools very clean, PJSM for loading chemical into tools, discuss cutter hazards, working at heights, contingency plan in case of failure, test water hose on RF to be operating normally. discussed eye wash station and shower locations. Clear RF 8,868.0 8,868.0 10/15/2021 20:42 10/15/2021 22:36 1.90 PROD1, DRILL ELNE P Load Chemical, get a zero at RF, PU and load tools into coil, RIH to 200', 8,868.0 8,868.0 10/15/2021 22:36 10/15/2021 22:48 0.20 PROD1, DRILL ELNE P 8,795'. witness cutter fire, seen a little movement/weight bobble on E-line Unit, PUW 1,038 lbs 8,868.0 8,868.0 10/15/2021 22:48 10/16/2021 00:00 1.20 PROD1, DRILL ELNE P 8,795', Hung up with e-line, work to get free, continue OOH 8,868.0 8,868.0 10/16/2021 00:00 10/16/2021 00:15 0.25 PROD1, DRILL ELNE P Continue POOH with Eline 8,868.0 8,868.0 10/16/2021 00:15 10/16/2021 00:33 0.30 PROD1, DRILL ELNE P At surface, flow check well, PJSM for laying down cutterr 8,868.0 8,868.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 14/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/16/2021 00:33 10/16/2021 01:03 0.50 PROD1, DRILL ELNE P LD/inspect/confirm cutter operation, cutter functioned properly. 8,868.0 8,868.0 10/16/2021 01:03 10/16/2021 02:15 1.20 PROD1, DRILL ELNE P Line up to circulate 9.8 ppg NaCI down the annulus (100 bbls) 8,868.0 8,868.0 10/16/2021 02:15 10/16/2021 03:15 1.00 PROD1, DRILL ELNE P Line up circulate 9.8 ppg NaCl down the coil (60 bbls) 8,868.0 8,868.0 10/16/2021 03:15 10/16/2021 04:15 1.00 PROD1, DRILL ELNE P Check well and coil for flow (no flow), pull to 27k 8,868.0 8,868.0 10/16/2021 04:15 10/16/2021 04:33 0.30 PROD1, DRILL ELNE P Back out Manual locks, and function open Upper and Lower pipe rams 8,868.0 8,868.0 10/16/2021 04:33 10/16/2021 04:51 0.30 PROD1, DRILL ELNE P Pull up 20' PUW 40k clean, indicating successful cut, RBIH, function closed Upper and Lower pipe/slip rams, manually lock in rams, set slips and dog collar, 8,868.0 8,868.0 10/16/2021 04:51 10/16/2021 06:51 2.00 PROD1, DRILL ELNE P RD/LD E-line - rig crews demo scaffold and stage bucket at foot of beaver slide. 8,868.0 8,868.0 10/16/2021 06:51 10/16/2021 09:21 2.50 PROD1, DRILL CTOP P PJSM, prep stump for cut. Scaffold crew on location, off load first bucket, remove rest of scaffold equip. Trim stump to 4' 8" height from rig floor. Ream tubing Skid cart with spoolable installed in storage reel side. Approx 24" clearance from bottom of quick union to top of coil. Stab CTC and dimple. Pull test to 30 k good. 8,868.0 8,868.0 10/16/2021 09:21 10/16/2021 11:33 2.20 PROD1, DRILL CTOP P Strip onto stump, make up quick union. PU wt 34 k lbs. Slowly pull spoolable connector to storage reel. Add 4 full wraps then ramp up POOH speed. Call out LRS mid trip 8,795.0 500.0 10/16/2021 11:33 10/16/2021 12:27 0.90 PROD1, DRILL CTOP P Near surface,fill hole the rig floor. Verify no flow. Follow slim BHA procedure to surface. Fill hole - flow check - well on a vac - LRS on location, spot up rig up in cellar tie onto test valves. 1.3 bbl fill up after 5 min - 15.6 bbl/hr 3.5 bbl fill up after 20 min - 10.5 bbl/hr Pop off well with whats left of BHA #10 500.0 0.0 10/16/2021 12:27 10/16/2021 13:57 1.50 DEMOB, WHDBOP CTOP P Bullhead 35 bbls diesel FP via the test valves on lower BOP rams. 750 psi @ 1.5 bpm 34 bbls pumped, shut down. ***Final WH -0, IA 73, and OA 93 psi 0.0 0.0 10/16/2021 13:57 10/16/2021 15:57 2.00 DEMOB, WHDBOP CTOP P N2 on location, RU, cool down, PT 4,000 psi, Come on line for 15 minutes at 1,500 SCF/min. Trap pressure in coil, blow down bleed off. Release Nitrogen. 0.0 0.0 10/16/2021 15:57 10/16/2021 17:27 1.50 DEMOB, WHDBOP CTOP P flush and blow down 0.0 0.0 10/16/2021 17:27 10/16/2021 18:03 0.60 DEMOB, WHDBOP SFTY P Pre-tour, crew change, PJSM for RD 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 Page 15/15 1B-10 Report Printed: 10/26/2021 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/16/2021 18:03 10/17/2021 00:00 5.95 DEMOB, WHDBOP RURD P RD, MT pits and off load TT, remove transducers, nipple down stack, break down dike around cellar (3"x12"), secure cellar for pulling off well, blow down steam, drain line blown down, secure reel, INJH, and PDL's for transport, Load out rig equipment on KDTH trucks *** Rig Released @ Midnight ***. Continue to work RD checklist, call for fuel for halfway house, load out KDTH trucks *** Rig Released @ Midnight ***. 0.0 0.0 Rig: NABORS CDR3-AC RIG RELEASE DATE 10/17/2021 !" !#$ #%& 50-029-20656-60 '( ( &%$ ( )* ( ( #!+, -( -( ! !".$(# !$%&'!! ( !) ,( !" (*+, . ( !$%&'!! ( !) / ( - ! * . ( 0( ' . 1( (%./( ) 0,%./(0,1010) 20 , 2 , 3!4 #" 5- 55 - - &,$( &$( ,( /,( 23%- 2/3% " 0$&( ! !'!! !'!! +2%6%264/'!! +4%27&'!! !'!!-$( !'!! /!8%94!'770 4%8769+'7&- - 456 7$, 4)6 8, 456 !" .$/., ::#.!. !;;.!. +'.& &!'/ +/2.&6'!/ (* ( 8$/ ( , !" 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') ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit_1 Kupark 1B Pad 1B-10L1PB1 50-029-20656-70 ConocoPhillips Definitive Survey Report 27 October, 2021 Baker Hughes Definitive Survey Report Company:ConocoPhillips Local Co-ordinate Reference:Well 1B-10 Project: Site: Well: Wellbore: Design: Kuparuk River Unit_1 Kupark 1B Pad 1B-10 1B-10L1PB1 1B-10L1PB1 TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 1B-10 @ 98.00usft (1B-10) 1B-10 @ 98.00usft (1B-10) True Minimum Curvature EDT 15 Alaska Prod Project Kuparuk River Unit_1, North Slope Alaska, United States Map System: Geo Datum: Map Zone: Well Well Position US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 1B-10 System Datum: 5,969,647.0 549,138.0 Mean Sea Level Using Well Reference Point Using geodetic scale factor Latitude: Longitude: Position Uncertainty Wellbore Magnetics 1B-10L1PB1 Model Name 0.00 usft Sample Date Declination (°) Ground Level: Dip Angle (°) 0.00usft BGGM2021 10/1/2021 15.28 80.71 57,286.07 Design Audit Notes: Version: 1B-10L1PB1 1.0 Phase:ACTUAL Tie On Depth:8,800.00 Vertical Section: Depth From (TVD) (usft) 98.00 +N/-S (usft) 0.00 +E/-W (usft) 0.00 Direction (°) 26.65 Survey Program From (usft) To (usft) Date 10/27/2021 Survey (Wellbore) Tool Name Description Survey Date 100.00 8,800.00 1B-10 (1B-10) 8,845.00 8,865.00 1B-10L1PB1 (1B-10L1PB1) BOSS-GYRO Sperry-Sun BOSS gyro multishot BLIND Blind drilling 8/25/2000 12:00:00AM 10/27/2021 11:52:00AM Survey MD (usft) Inc (°) Azi (°) TVD (usft) TVDSS (usft) +N/-S (usft) +E/-W (usft) Map Northing (ft) Map Easting (ft) DLS (°/100') Vertical Section (ft)Survey Tool Name 98.00 0.00 0.00 98.00 0.00 0.00 0.00 5,969,647.00 549,138.00 0.00 0.00 UNDEFINED 100.00 0.33 184.50 100.00 2.00 -0.01 0.00 5,969,646.99 549,138.00 16.50 -0.01 BOSS-GYRO (1) 200.00 0.23 251.30 200.00 102.00 -0.36 -0.21 5,969,646.64 549,137.79 0.32 -0.41 BOSS-GYRO (1) 300.00 0.17 198.00 300.00 202.00 -0.56 -0.45 5,969,646.43 549,137.55 0.19 -0.70 BOSS-GYRO (1) 400.00 0.07 108.90 400.00 302.00 -0.72 -0.44 5,969,646.27 549,137.57 0.18 -0.84 BOSS-GYRO (1) 500.00 0.68 13.80 500.00 402.00 -0.17 -0.24 5,969,646.83 549,137.76 0.69 -0.26 BOSS-GYRO (1) 600.00 2.25 353.00 599.96 501.96 2.36 -0.34 5,969,649.36 549,137.65 1.63 1.96 BOSS-GYRO (1) 700.00 3.88 1.40 699.81 601.81 7.69 -0.49 5,969,654.68 549,137.46 1.69 6.65 BOSS-GYRO (1) 800.00 5.97 14.00 799.44 701.44 16.12 0.85 5,969,663.12 549,138.74 2.34 14.79 BOSS-GYRO (1) 900.00 8.92 15.40 898.59 800.59 28.64 4.17 5,969,675.67 549,141.98 2.96 27.47 BOSS-GYRO (1) 1,000.00 11.25 14.20 997.04 899.04 45.57 8.62 5,969,692.63 549,146.32 2.34 44.60 BOSS-GYRO (1) 1,100.00 15.73 14.30 1,094.25 996.25 68.18 14.36 5,969,715.26 549,151.91 4.48 67.38 BOSS-GYRO (1) 1,200.00 20.20 21.50 1,189.37 1,091.37 97.40 24.04 5,969,744.54 549,161.40 4.98 97.83 BOSS-GYRO (1) 10/27/2021 2:53:39PM Page 2 COMPASS 5000.15 Build 91E +N/-S +E/-W 0.00 usft 0.00 usft Northing: Easting: 0 usft 70° 19' 40.313 N 0 usft 149° 36' 5.381 W Wellhead Elevation:usft Field Strength (nT) Baker Hughes Definitive Survey Report Company:ConocoPhillips Local Co-ordinate Reference:Well 1B-10 Project: Site: Well: Wellbore: Design: Survey Kuparuk River Unit_1 Kupark 1B Pad 1B-10 1B-10L1PB1 1B-10L1PB1 TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 1B-10 @ 98.00usft (1B-10) 1B-10 @ 98.00usft (1B-10) True Minimum Curvature EDT 15 Alaska Prod MD (usft) Inc (°) Azi (°) TVD (usft) TVDSS (usft) +N/-S (usft) +E/-W (usft) Map Northing (ft) Map Easting (ft) DLS (°/100') Vertical Section (ft)Survey Tool Name 1,250.00 22.52 23.00 1,235.93 1,137.93 114.24 30.95 5,969,761.43 549,168.20 4.77 115.99 BOSS-GYRO (1) 1,300.00 25.15 27.00 1,281.66 1,183.66 132.53 39.52 5,969,779.77 549,176.64 6.17 136.17 BOSS-GYRO (1) 1,350.00 27.38 29.80 1,326.50 1,228.50 151.98 50.06 5,969,799.29 549,187.06 5.10 158.28 BOSS-GYRO (1) 1,400.00 29.57 30.50 1,370.45 1,272.45 172.58 62.03 5,969,819.97 549,198.90 4.43 182.07 BOSS-GYRO (1) 1,500.00 33.23 27.50 1,455.79 1,357.79 218.17 87.22 5,969,865.71 549,223.78 3.98 234.11 BOSS-GYRO (1) 1,550.00 33.42 22.60 1,497.58 1,399.58 243.04 98.84 5,969,890.65 549,235.23 5.40 261.55 BOSS-GYRO (1) 1,600.00 34.00 17.70 1,539.18 1,441.18 269.07 108.38 5,969,916.75 549,244.61 5.56 289.10 BOSS-GYRO (1) 1,700.00 38.20 17.60 1,619.96 1,521.96 325.21 126.24 5,969,972.99 549,262.10 4.20 347.28 BOSS-GYRO (1) 1,750.00 40.63 20.10 1,658.59 1,560.59 355.24 136.51 5,970,003.09 549,272.17 5.80 378.73 BOSS-GYRO (1) 1,800.00 42.97 20.60 1,695.86 1,597.86 386.48 148.10 5,970,034.40 549,283.55 4.73 411.85 BOSS-GYRO (1) 1,900.00 43.73 19.00 1,768.58 1,670.58 451.06 171.35 5,970,099.13 549,306.37 1.34 480.00 BOSS-GYRO (1) 2,000.00 42.03 19.70 1,841.86 1,743.86 515.27 193.89 5,970,163.47 549,328.49 1.77 547.49 BOSS-GYRO (1) 2,100.00 40.37 19.40 1,917.09 1,819.09 577.33 215.93 5,970,225.68 549,350.12 1.67 612.85 BOSS-GYRO (1) 2,200.00 39.02 20.20 1,994.04 1,896.04 637.43 237.56 5,970,285.91 549,371.36 1.44 676.26 BOSS-GYRO (1) 2,300.00 37.62 20.30 2,072.49 1,974.49 695.60 259.02 5,970,344.21 549,392.43 1.40 737.88 BOSS-GYRO (1) 2,400.00 36.33 20.30 2,152.38 2,054.38 752.01 279.89 5,970,400.75 549,412.93 1.29 797.65 BOSS-GYRO (1) 2,500.00 35.18 20.30 2,233.53 2,135.53 806.81 300.16 5,970,455.68 549,432.84 1.15 855.73 BOSS-GYRO (1) 2,600.00 35.63 20.10 2,315.04 2,217.04 861.18 320.16 5,970,510.18 549,452.48 0.46 913.29 BOSS-GYRO (1) 2,700.00 39.57 20.40 2,394.25 2,296.25 918.41 341.28 5,970,567.54 549,473.23 3.94 973.92 BOSS-GYRO (1) 2,800.00 44.40 21.50 2,468.56 2,370.56 980.85 365.22 5,970,630.13 549,496.75 4.89 1,040.46 BOSS-GYRO (1) 2,850.00 46.57 21.00 2,503.62 2,405.62 1,014.08 378.14 5,970,663.44 549,509.45 4.40 1,075.95 BOSS-GYRO (1) 2,900.00 49.77 21.50 2,536.96 2,438.96 1,048.80 391.64 5,970,698.24 549,522.73 6.44 1,113.04 BOSS-GYRO (1) 3,000.00 51.98 22.00 2,600.06 2,502.06 1,120.84 420.39 5,970,770.46 549,551.00 2.24 1,190.33 BOSS-GYRO (1) 3,100.00 52.67 21.70 2,661.17 2,563.17 1,194.31 449.85 5,970,844.11 549,579.98 0.73 1,269.20 BOSS-GYRO (1) 3,200.00 52.57 21.90 2,721.88 2,623.88 1,268.09 479.36 5,970,918.08 549,609.00 0.19 1,348.38 BOSS-GYRO (1) 3,300.00 52.88 22.10 2,782.45 2,684.45 1,341.87 509.17 5,970,992.04 549,638.32 0.35 1,427.69 BOSS-GYRO (1) 3,400.00 52.92 22.00 2,842.77 2,744.77 1,415.79 539.11 5,971,066.15 549,667.78 0.09 1,507.19 BOSS-GYRO (1) 3,500.00 53.32 22.50 2,902.78 2,804.78 1,489.82 569.40 5,971,140.38 549,697.58 0.57 1,586.94 BOSS-GYRO (1) 3,600.00 54.15 22.90 2,961.93 2,863.94 1,564.21 600.52 5,971,214.95 549,728.20 0.89 1,667.38 BOSS-GYRO (1) 3,700.00 54.75 23.70 3,020.08 2,922.08 1,638.93 632.70 5,971,289.88 549,759.89 0.89 1,748.60 BOSS-GYRO (1) 3,800.00 55.32 23.20 3,077.38 2,979.38 1,714.11 665.31 5,971,365.26 549,792.01 0.70 1,830.42 BOSS-GYRO (1) 3,900.00 56.52 24.20 3,133.42 3,035.42 1,789.95 698.60 5,971,441.31 549,824.80 1.46 1,913.13 BOSS-GYRO (1) 4,000.00 56.70 24.10 3,188.45 3,090.45 1,866.13 732.76 5,971,517.71 549,858.46 0.20 1,996.55 BOSS-GYRO (1) 4,100.00 56.72 24.20 3,243.34 3,145.34 1,942.41 766.96 5,971,594.20 549,892.15 0.09 2,080.06 BOSS-GYRO (1) 4,200.00 57.87 25.60 3,297.37 3,199.37 2,018.72 802.40 5,971,670.74 549,927.08 1.65 2,164.16 BOSS-GYRO (1) 4,300.00 58.77 26.50 3,349.89 3,251.89 2,095.18 839.77 5,971,747.43 549,963.95 1.18 2,249.25 BOSS-GYRO (1) 4,400.00 56.88 28.70 3,403.14 3,305.14 2,170.18 878.96 5,971,822.68 550,002.65 2.65 2,333.87 BOSS-GYRO (1) 4,500.00 54.87 28.40 3,459.24 3,361.24 2,242.89 918.53 5,971,895.64 550,041.73 2.03 2,416.60 BOSS-GYRO (1) 4,600.00 55.50 28.50 3,516.33 3,418.33 2,315.08 957.64 5,971,968.07 550,080.36 0.64 2,498.66 BOSS-GYRO (1) 4,700.00 55.72 28.90 3,572.82 3,474.82 2,387.46 997.27 5,972,040.71 550,119.51 0.40 2,581.13 BOSS-GYRO (1) 10/27/2021 2:53:39PM Page 3 COMPASS 5000.15 Build 91E Baker Hughes Definitive Survey Report Company:ConocoPhillips Local Co-ordinate Reference:Well 1B-10 Project: Site: Well: Wellbore: Design: Survey Kuparuk River Unit_1 Kupark 1B Pad 1B-10 1B-10L1PB1 1B-10L1PB1 TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 1B-10 @ 98.00usft (1B-10) 1B-10 @ 98.00usft (1B-10) True Minimum Curvature EDT 15 Alaska Prod MD (usft) Inc (°) Azi (°) TVD (usft) TVDSS (usft) +N/-S (usft) +E/-W (usft) Map Northing (ft) Map Easting (ft) DLS (°/100') Vertical Section (ft)Survey Tool Name 4,800.00 55.88 28.80 3,629.02 3,531.02 2,459.90 1,037.18 5,972,113.40 550,158.94 0.18 2,663.78 BOSS-GYRO (1) 4,900.00 56.20 29.00 3,684.89 3,586.89 2,532.52 1,077.26 5,972,186.27 550,198.55 0.36 2,746.66 BOSS-GYRO (1) 5,000.00 56.18 28.90 3,740.53 3,642.53 2,605.22 1,117.48 5,972,259.23 550,238.29 0.09 2,829.68 BOSS-GYRO (1) 5,100.00 57.12 29.10 3,795.50 3,697.50 2,678.28 1,157.98 5,972,332.55 550,278.30 0.95 2,913.14 BOSS-GYRO (1) 5,200.00 56.92 29.60 3,849.94 3,751.94 2,751.40 1,199.09 5,972,405.93 550,318.93 0.46 2,996.93 BOSS-GYRO (1) 5,300.00 57.17 29.70 3,904.34 3,806.34 2,824.32 1,240.60 5,972,479.11 550,359.96 0.26 3,080.73 BOSS-GYRO (1) 5,400.00 57.90 29.40 3,958.02 3,860.02 2,897.72 1,282.21 5,972,552.77 550,401.08 0.77 3,164.99 BOSS-GYRO (1) 5,500.00 57.98 29.50 4,011.10 3,913.10 2,971.52 1,323.88 5,972,626.83 550,442.26 0.12 3,249.64 BOSS-GYRO (1) 5,600.00 58.23 29.20 4,063.93 3,965.93 3,045.52 1,365.50 5,972,701.10 550,483.39 0.36 3,334.45 BOSS-GYRO (1) 5,700.00 58.43 29.60 4,116.43 4,018.44 3,119.67 1,407.28 5,972,775.51 550,524.68 0.39 3,419.46 BOSS-GYRO (1) 5,800.00 57.82 30.90 4,169.24 4,071.24 3,193.02 1,450.05 5,972,849.14 550,566.97 1.26 3,504.21 BOSS-GYRO (1) 5,900.00 59.23 30.10 4,221.46 4,123.46 3,266.51 1,493.33 5,972,922.90 550,609.76 1.57 3,589.30 BOSS-GYRO (1) 6,000.00 59.47 30.40 4,272.43 4,174.43 3,340.82 1,536.67 5,972,997.49 550,652.61 0.35 3,675.16 BOSS-GYRO (1) 6,100.00 59.00 30.60 4,323.59 4,225.59 3,414.86 1,580.28 5,973,071.81 550,695.73 0.50 3,760.89 BOSS-GYRO (1) 6,200.00 59.30 30.90 4,374.87 4,276.87 3,488.64 1,624.18 5,973,145.87 550,739.14 0.40 3,846.52 BOSS-GYRO (1) 6,300.00 59.73 31.10 4,425.60 4,327.60 3,562.51 1,668.56 5,973,220.01 550,783.03 0.46 3,932.45 BOSS-GYRO (1) 6,400.00 59.30 31.20 4,476.33 4,378.33 3,636.26 1,713.14 5,973,294.05 550,827.12 0.44 4,018.36 BOSS-GYRO (1) 6,500.00 59.52 31.60 4,527.22 4,429.22 3,709.74 1,757.99 5,973,367.81 550,871.49 0.41 4,104.15 BOSS-GYRO (1) 6,600.00 57.67 31.70 4,579.32 4,481.32 3,782.39 1,802.77 5,973,440.75 550,915.79 1.85 4,189.17 BOSS-GYRO (1) 6,700.00 54.57 30.40 4,635.06 4,537.06 3,853.50 1,845.60 5,973,512.12 550,958.15 3.28 4,271.93 BOSS-GYRO (1) 6,800.00 50.83 30.20 4,695.65 4,597.65 3,922.16 1,885.73 5,973,581.05 550,997.82 3.74 4,351.31 BOSS-GYRO (1) 6,900.00 46.93 28.80 4,761.40 4,663.40 3,987.70 1,922.84 5,973,646.82 551,034.50 4.04 4,426.53 BOSS-GYRO (1) 7,000.00 44.42 28.60 4,831.27 4,733.27 4,050.44 1,957.20 5,973,709.78 551,068.44 2.51 4,498.01 BOSS-GYRO (1) 7,100.00 41.60 27.10 4,904.39 4,806.39 4,110.73 1,989.08 5,973,770.27 551,099.92 3.00 4,566.20 BOSS-GYRO (1) 7,200.00 38.27 26.40 4,981.06 4,883.06 4,168.04 2,017.98 5,973,827.76 551,128.44 3.36 4,630.38 BOSS-GYRO (1) 7,300.00 36.48 26.80 5,060.52 4,962.52 4,222.32 2,045.15 5,973,882.21 551,155.26 1.81 4,691.08 BOSS-GYRO (1) 7,400.00 36.05 27.90 5,141.15 5,043.15 4,274.86 2,072.33 5,973,934.92 551,182.09 0.78 4,750.23 BOSS-GYRO (1) 7,500.00 35.33 27.30 5,222.37 5,124.37 4,326.56 2,099.36 5,973,986.79 551,208.77 0.80 4,808.56 BOSS-GYRO (1) 7,600.00 34.45 28.00 5,304.39 5,206.39 4,377.23 2,125.90 5,974,037.63 551,234.98 0.97 4,865.75 BOSS-GYRO (1) 7,700.00 33.58 30.00 5,387.29 5,289.29 4,426.15 2,153.01 5,974,086.73 551,261.76 1.42 4,921.64 BOSS-GYRO (1) 7,800.00 32.87 28.70 5,470.94 5,372.94 4,473.91 2,179.87 5,974,134.65 551,288.31 1.01 4,976.36 BOSS-GYRO (1) 7,900.00 32.07 29.60 5,555.31 5,457.31 4,520.79 2,206.01 5,974,181.70 551,314.14 0.93 5,030.00 BOSS-GYRO (1) 8,000.00 32.82 29.10 5,639.70 5,541.70 4,567.56 2,232.30 5,974,228.63 551,340.13 0.80 5,083.59 BOSS-GYRO (1) 8,100.00 32.03 30.10 5,724.10 5,626.11 4,614.18 2,258.78 5,974,275.42 551,366.30 0.95 5,137.13 BOSS-GYRO (1) 8,200.00 30.93 31.00 5,809.39 5,711.39 4,659.15 2,285.32 5,974,320.56 551,392.54 1.20 5,189.23 BOSS-GYRO (1) 8,300.00 30.27 31.90 5,895.46 5,797.46 4,702.58 2,311.87 5,974,364.16 551,418.80 0.80 5,239.96 BOSS-GYRO (1) 8,400.00 29.67 32.70 5,982.09 5,884.09 4,744.80 2,338.56 5,974,406.56 551,445.21 0.72 5,289.67 BOSS-GYRO (1) 8,500.00 29.15 34.80 6,069.20 5,971.20 4,785.63 2,365.84 5,974,447.56 551,472.22 1.15 5,338.39 BOSS-GYRO (1) 8,600.00 28.17 35.30 6,156.95 6,058.95 4,824.90 2,393.38 5,974,487.00 551,499.50 1.01 5,385.84 BOSS-GYRO (1) 8,700.00 27.30 38.40 6,245.47 6,147.47 4,862.13 2,421.26 5,974,524.41 551,527.14 1.68 5,431.63 BOSS-GYRO (1) 10/27/2021 2:53:39PM Page 4 COMPASS 5000.15 Build 91E Baker Hughes Definitive Survey Report Company:ConocoPhillips Local Co-ordinate Reference:Well 1B-10 Project: Site: Well: Wellbore: Design: Survey Kuparuk River Unit_1 Kupark 1B Pad 1B-10 1B-10L1PB1 1B-10L1PB1 TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 1B-10 @ 98.00usft (1B-10) 1B-10 @ 98.00usft (1B-10) True Minimum Curvature EDT 15 Alaska Prod MD (usft) Inc (°) Azi (°) TVD (usft) TVDSS (usft) +N/-S (usft) +E/-W (usft) Map Northing (ft) Map Easting (ft) DLS (°/100') Vertical Section (ft)Survey Tool Name 8,800.00 27.45 39.70 6,334.27 6,236.27 4,897.84 2,450.23 5,974,560.31 551,555.87 0.62 5,476.53 BLIND (2) Tie On Point 8,845.00 27.28 40.28 6,374.23 6,276.23 4,913.69 2,463.52 5,974,576.24 551,569.05 0.70 5,496.66 BLIND (2) Top of Whipstock 8,865.00 33.28 40.28 6,391.50 6,293.50 4,921.38 2,470.04 5,974,583.97 551,575.52 30.00 5,506.46 BLIND (2) Projection to TD 10/27/2021 2:53:39PM Page 5 COMPASS 5000.15 Build 91E From:Germann, Shane To:Guhl, Meredith D (CED) Subject:RE: [EXTERNAL]PTD 220-032, KRU 1B-10 L1 PB1: electrical logs? Date:Monday, November 15, 2021 9:35:11 AM Hi Meredith, No logs were ran in the PB1. We were only able to mill the window and rathole before having to abandon the window and move to the backup. Thanks, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Monday, November 15, 2021 9:27 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]PTD 220-032, KRU 1B-10 L1 PB1: electrical logs? CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Shane, Were electrical logs run in the PB1 leg of the KRU 1B-10L1? Only surveys have been submitted so far. Thanks, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA November 10, 2021 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. 1B-10L1PB1 Kuparuk River API #: 50-029-20656-70 Permit No: 220-032 Rig: CDR3 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jenny Jones Jenny.E.Jones@conocophillips.com Melissa LeMay Melissa.LeMay@bakerhughes.com 15% &4FU 11/12/2021 By Abby Bell at 1:07 pm, Nov 10, 2021 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA November 10, 2021 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. 1B-10L1 Kuparuk River API #: 50-029-20656-60-00 Permit No: 220-032 Rig: CDR3 The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jenny Jones Jenny.E.Jones@conocophillips.com Melissa LeMay Melissa.LeMay@bakerhughes.com 15% &4FU 11/12/2021 By Abby Bell at 11:32 am, Nov 10, 2021 From:Germann, Shane To:Loepp, Victoria T (OGC) Cc:Ohlinger, James J Subject:KRU 1B-10L1 (PTD #220-032) 10/13 Update Date:Wednesday, October 13, 2021 12:56:52 PM Hello Victoria, This is to inform you that we have a stuck BHA in the window on KRU 1B-10 L1 (PTD # 220-032) with Nabors CDR3. Background: Nabors CDR3 milled the window at our backup KOP @ 8821’ MD. We were able to drill the permitted L1 lateral to 9905’ MD before discovering issues with the window. During a camera run to examine the window area we became stuck with top of BHA @ 8821’ MD and bottom of BHA @ 8837’ MD. Working pipe yielded no results. Path Forward: We are commencing pipe recovery operations and are working a plan forward to fish the BHA out of the window following pipe recovery and reel swap. Our goal is to successfully fish the BHA and run liner per plan. Please contact me if you have any questions. This was an update email to keep you informed on our operations. Thank you for your time. Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.I.Supry1D�k BOPE Test Report for: KUPARUK RIV UNIT IB -IOL] Comm Contractor/Rig No.: Nabors CDR3AC Operator: ConocoPhillips Alaska, Inc. Type Operation: DRILL Sundry No: Type Test: INIT PTD#: 2200320 - DATE: 10/3/2021 ' Inspector Brian Bixby ' Insp Source Operator Rep: M. Shotenski / C. Erdman Rig Rep: C. Coyne / N. Wheeler Inspector Test Pressures: Rams: Annular: Valves: MASP: 250/5000 250/2500 - 250/5000 2819 - TEST DATA Inspection No: bopBDB211004150655 Related Insp No: MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: CHOKE MANIFOLD: P/F P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P P - System Pressure _ _ 3000---- P -- -Housekeeping: Housekeeping: P Pit Level Indicators P P ' Pressure After Closure 2350 P PTD On Location P Flow Indicator P- P-- 200 PSI Attained 23 P Standing Order Posted P Meth Gas Detector __P - P Full Pressure Attained 47 " P Well Sign P H2S Gas Detector P - P Blind Switch Covers: YES P Drl. Rig P MS Misc 0 NA Nitgn. Bottles (avg): 4@2020spi- P " Hazard Sec. P #4 Rams 1 2" Combi P ACC Misc 0 NA Mise NA #5 Rams 0 NA INSIDE REEL VALVES: FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 0__' NA- Stripper 1_- 2" P No. Valves 12 P - Lower Kelly 0 NA - Annular Preventer 1 7 1/16" P Manual Chokes 1 P - Ball Type 2 P #1 Rams 1 Blind Shear P Hydraulic Chokes I - P - Inside BOP 0 - NA" #2 Rams 1 " 2" Combi P CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 '2 3/8" Combi FP v #4 Rams 1 2" Combi P #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 2 1/16" FP ✓ Quantity P/F HCR Valves 2- 2 1/16" FP Inside Reel Valves 1_ - _ P - Kill Line Valves 5 2 1/16" FP Check Valve 0 NA BOP Misc 3 ' 4 1/16" P Number of Failures: 4 ✓ Test Results Test Time 12 Remarks: Tested all gas alarms and PVT's, Manual Kill, Manual choke and HCR Choke on the stack all failed were serviced and passed retest. 2 3/8" combi equalizer valve was tightened and then it passed the retest. ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT INSPECT DATE 10/2/2021 AOGCC INSPECTOR Brian Bixby Rig Nabors CDR3AC Rig Contractor Nabors Alaska Drilling Operator Conoco Alaska LLC Well KRU 113-101-1 Operation Drilling BOP STACK CLOSING UNIT Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote Firewall 2 or More Pumps Independent Power Supply N2 Backup Condition of Equipment CHOKE MANIFOLD Valves Remote Hydraulic Choke FOV Upstream of Chokes Targeted Turns Bypass Line Working Pressure, W/H Flange P Working Pressure, BOP Stack P Annular Preventer P Pipe Rams P Blind Rams P Locking Devices, Rams NT Stack Anchored P Choke Line FP Kill Line FP Targeted Turns P HCR Valve(s) FP Manual Valves P Flange/Hub Connections P Drilling Spool Outlets P Flow Nipple P Control Lines P MISCELLANEOUS CLOSING UNIT Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote Firewall 2 or More Pumps Independent Power Supply N2 Backup Condition of Equipment CHOKE MANIFOLD Valves Remote Hydraulic Choke FOV Upstream of Chokes Targeted Turns Bypass Line PPE P Well Control Trained P Housekeeping P Well Control Plan P FAILURES: 4 P.I. Supv J J2 �GlZ6�ZCLl Comm: Coil Tubing Unit? Yes Rig Representative M. Shotenski / C. Erdman Contractor Representative C. Coyne / N. Wheeler Permit to Drill # Inspection Location MUD SYSTEM Pit Fluid Measurement Flow Rate Sensor Mud Gas Separator Degasser Separator Bypass Gas Detectors Alarms Separate/Distinct Choke/Kill Line Connections Reserve Pits Trip Tank RIG FLOOR Kelly or TD Valves Floor Safety Valves Driller's Console Flow Monitor Flow Rate Indicator Pit Level Indicators Gauges Gas Detection Monitor Hydraulic Control Panel Kill Sheet Current CORRECT BY 2200320 Sundry Approval # KRU 1B -10L1 Done before left location COMMENTS Manual Kill, Manual Choke and HCR choke valves on the stack failed were serviced and passed retest. The 2 3/8" combi's equalizer valve was tightened and passed retest. 2021-1002_Rig_Nabors_CDR3AC_KRU_1 B-10L1_bb rev. 5-8-18 CLOSING UNIT Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote Firewall 2 or More Pumps Independent Power Supply N2 Backup Condition of Equipment CHOKE MANIFOLD Valves Remote Hydraulic Choke FOV Upstream of Chokes Targeted Turns Bypass Line P P P P P P P P P - P P P P P P P - P P P P P P P P P P P P NA P NA P P P P P P P P P Done before left location COMMENTS Manual Kill, Manual Choke and HCR choke valves on the stack failed were serviced and passed retest. The 2 3/8" combi's equalizer valve was tightened and passed retest. 2021-1002_Rig_Nabors_CDR3AC_KRU_1 B-10L1_bb rev. 5-8-18 1 Guhl, Meredith D (OGC) From:Germann, Shane <Shane.Germann@conocophillips.com> Sent:Wednesday, October 6, 2021 9:33 AM To:Loepp, Victoria T (OGC) Cc:Ohlinger, James J Subject:KRU 1B-10L1 (PTD# 220-032) Update Follow Up Flag:Follow up Flag Status:Flagged Good Morning Victoria, This is to inform you that we will be utilizing our backup kickoff point for KRU 1B‐10L1 (PTD # 220‐032). Background: Nabors CDR3 milled the first window @8845’ MD to rathole TD depth of 8865’ MD, but during passes through the window we deemed it to be in unsuitable condition. The KRU 1B‐10L1PB1 plugback will be from 8845’ MD (top of whipstock) to 8865’ MD (end of rathole). Path Forward: CDR3 plans to set a new whipstock at our backup KOP location @ 8820’ MD (proposed top of whipstock) and drill the 1B‐10L1 permitted lateral. Nabors CDR3 will be setting the whipstock today (10/6/2021). See the updated proposed schematic below for clarification. Please contact me if you have any questions. Thank you for your time. 2 Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907‐263‐4597 Cell: 406‐670‐1939 700 G St, ATO 664, Anchorage, AK 99501 From:Germann, Shane To:Loepp, Victoria T (OGC); Ohlinger, James J Cc:Regg, James B (OGC); DOA AOGCC Prudhoe Bay Subject:RE: [EXTERNAL]KRU 1B-10L1(PTD 220-032) Change in initial BOP test pressure to 5000 psi Date:Friday, October 1, 2021 8:41:36 AM Victoria, The rig has been notified and the initial BOPE test pressure will be to 5000 psi. I will mark the changes on our approved PTD. Thank you for the heads up. Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, September 30, 2021 10:21 PM To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Cc: Germann, Shane <Shane.Germann@conocophillips.com>; Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]KRU 1B-10L1(PTD 220-032) Change in initial BOP test pressure to 5000 psi CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. James, With the CDR3 startup after an extended shutdown, the initial BOPE test pressure must be to 5000 psi on the first well. KRU 1B-10L was approved 4/1/2020 and since this well is now the first well on startup of CDR3, the BOP test pressure is modified to 5000 psi. Please update your approved copy of the PTD with this change in initial BOPE test pressure and communicate this information to the rig. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1B-10L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 220-032 Surface Location: 494’FNL, 1301’FEL, SEC. 9, T11N, R10E, UM Bottomhole Location: 1238’FSL, 1219’FEL, SEC. 4, T11N, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of April, 2020. Sincerely, Jeremy M Price ! 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BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 23, 2020 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a lateral out of the KRU 1B-10 (PTD# 181-135) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin the second week of April 2020. The objective will be to drill a lateral KRU 1B-10L1 targeting the Kuparuk C-sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500’ from the original point. Attached to this application are the following documents: Permit to Drill Application Form (10-401) for 1B-10L1 Detailed Summary of Operations Directional Plans for 1B-10 Current wellbore schematic Proposed CTD schematic If you have any questions or require additional information, please contact me at 406-670-1939. Sincerely, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1B-10L1 Application for Permit to Drill Document Page 1 of 6 March 23, 2020 1. Well Name and Classification......................................................................................................... 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) .................................................................................................................. 2 2. Location Summary .......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)) ................................................................................................................................................. 2 3. Blowout Prevention Equipment Information ................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3)) ................................................................................................................................................ 2 4. Drilling Hazards Information and Reservoir Pressure .................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)) ................................................................................................................................................ 2 5. Procedure for Conducting Formation Integrity tests .................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)) ................................................................................................................................................. 2 6. Casing and Cementing Program .................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) ................................................................................................................................................. 3 7. Diverter System Information .......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................................. 3 8. Drilling Fluids Program................................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(8)) ................................................................................................................................................. 3 9. Abnormally Pressured Formation Information ............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)) ................................................................................................................................................. 4 10. Seismic Analysis ............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)) ............................................................................................................................................... 4 11. Seabed Condition Analysis ............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11)) ............................................................................................................................................... 4 12. Evidence of Bonding ...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12)) ............................................................................................................................................... 4 13. Proposed Drilling Program ............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13)) ............................................................................................................................................... 4 Summary of Operations................................................................................................................................................... 4 Liner Running .................................................................................................................................................................. 5 14. Disposal of Drilling Mud and Cuttings ........................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14)) ............................................................................................................................................... 5 15. Directional Plans for Intentionally Deviated Wells ........................................................................ 5 (Requirements of 20 AAC 25.050(b)) ..................................................................................................................................................... 5 16. Attachments .................................................................................................................................... 6 Attachment 1: Directional Plans for 1B-10L1 lateral ....................................................................................................... 6 Attachment 2: Current Well Schematic for 1B-10 ........................................................................................................... 6 Attachment 3: Proposed Well Schematic for 1B-10L1 lateral ......................................................................................... 6 PTD Application: 1B-10L1 Page 2 of 6 March 23, 2020 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed lateral described in this document is 1B-10L1. This lateral will be classified as “Development-Oil” wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1B-10L1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3,456 psi in 1B-05 (i.e. 10.03 ppg EMW). The maximum potential surface pressure in 1B-10, assuming a gas gradient of 0.1 psi/ft, would be 2,819 psi. See the “Drilling Hazards Information and Reservoir Pressure” section for more details. The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1B-10 was measured to be 3,044 psi (9.13 ppg EMW) on 10/18/2019. The maximum downhole pressure in the 1B-10 vicinity is in the 1B-05 at 3,456 psi (10.03 ppg EMW) from 1/26/2019. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) 1B-05 & 1B-09 are currently on MI injection so there is a possibility of encountering gas while drilling the 1B- 10L1 lateral. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problem in the 1B-10 lateral will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1B-10 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. PTD Application: 1B-10L1 Page 3 of 6 March 23, 2020 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top MD Liner Btm MD Liner Top TVDSS Liner Btm TVDSS Liner Details 8,835’ 14,000’ 6,267’ 6,259‘ 2-3/8", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System Window milling operations: Chloride-based PowerVis mud (8.6 ppg) Drilling operations: Chloride-based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. Completion operations: The well will be loaded with 10.7 ppg NaCl/NaBr completion fluid in order to provide formation over-balance and well bore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 “Blowout Prevention Equipment Information”. In the 1B-10 lateral we will target a constant BHP of 10.7 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. 1B-10L1 O.K. DLB PTD Application: 1B-10L1 Page 4 of 6 March 23, 2020 Pressure at the 1B-10 Window (8,845’ MD and 6,374’ TVD) Using MPD Pumps On (1.9 bpm) Pumps Off Formation Pressure (9.1 ppg) 3044 psi 3044 psi Mud Hydrostatic (8.6 ppg) 2850 psi 2850 psi Annular friction (i.e. ECD, 0.080 psi/ft) 708 psi 0 psi Mud + ECD Combined (no choke pressure) 3558 psi (overbalanced ~514 psi) 2850 psi (underbalanced ~194 psi) Target BHP at Window (10.7 ppg) 3558 psi 3558 psi Choke Pressure Required to Maintain Target BHP 0 psi 708 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations KRU well 1B-10 is a producer that was recently worked over to be set up for CTD operations. During the workover, 3 ½” tubing was installed with tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations CTU will cement squeeze the C4 perforations through a cement retainer and E-line will set an inner wedge within the tandem wedge. CDR3-AC will mill a window in the tubing and casing at 8,845 ’ MD. After that the 1B-10L1 lateral will be drilled to the southwest targeting the Kuparuk C-sand. The 1B-10L1 lateral will be completed with 2- 3/8” slotted liner with a deployment sleeve on top. Pre-CTD Work 1. RU Slickline: Drift, set X-lock 2. RU CTU: Cement squeeze C4 perfs 3. RU E-Line: Set inner wedge at 8,845’ MD 0° ROHS 4. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2” coil tubing. NU 7-1/16” BOPE, test. 2. 1B-10L1 Lateral (Kuparuk C-sand- Southwest) O.K. DLB PTD Application: 1B-10L1 Page 5 of 6 March 23, 2020 a. Mill 2.80” window at 8,845’ MD b. Drill 3” bi-center lateral to TD of 14,000’ MD. c. Run 2-3/8” slotted liner with deployment sleeve from TD up to 8,840’ MD. 3. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post-Rig Work 4. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running The 1B-10 lateral will be displaced to an overbalancing fluid (10.7 ppg NaCl/NaBr) prior to running liner. See “Drilling Fluids” section for more details. While running 2-3/8” slotted liner, a joint of 2-3/8” non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8” rams will provide secondary well control while running 2-3/8” liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) x No annular injection on this well. x All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. x Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. x All wastes and waste fluids hauled from the pad must be properly documented and manifested. x Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) The Applicant is the only affected owner. PTD Application: 1B-10L1 Page 6 of 6 March 23, 2020 Please see Attachment 1: Directional Plans Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1B-10L1 22,308’ Distance to Nearest Well within Pool Lateral Name Distance Well 1B-10L1 218’ KRU 1B-16 16. 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Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 8,975.0 6/7/2018 1B-10 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Gas lift valves. Added cement retainer 10/9/2019 1B-10 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.94 Top (ftKB) 31.3 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 91.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.35 Top (ftKB) 30.3 Set Depth (ftKB) 2,547.0 Set Depth (TVD) … 2,271.9 Wt/Len (l… 72.00 Grade N-80 Top Thread BTC Casing Description PRODUCTION OD (in) 9 5/8 ID (in) 8.86 Top (ftKB) 28.3 Set Depth (ftKB) 9,358.4 Set Depth (TVD) … 6,837.2 Wt/Len (l… 47.00 Grade L-80 Top Thread BUTT Tubing Strings Tubing Description TUBING 4.5 x3.5 x 2.875 WO 2019 UPPER COMPLETION String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.6 Set Depth (ft… 8,477.4 Set Depth (TVD) (… 6,049.5 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.6 23.6 0.08 HANGER FMC 13 5/8 x 4 1/2" New Standard Big Bore Tubing Hanger W/ 5" RH Acme top 3.910 1,799.4 1,695.5 42.94 SSSV Camco 4 1/2" TRMAXX-5E 3.812" SSSV 1797' 3.812 1,809.4 1,702.7 43.04 XO REDUCING XO Pup 4 1/2" IBTM Box x 3 1/2" EUE-Mod Pin 3.833 8,451.7 6,027.1 29.40 SBE Baker 3 1/2" EUE seal Assy 25.67' OAL buried below liner top New up 2.990 Tubing Description TUBING - 4.5 X 3.5 X 2.875 WO 2019 LOWER COMPLETION String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 8,423.2 Set Depth (ft… 8,902.5 Set Depth (TVD) (… 6,425.4 Wt (lb/ft) 9.30 Grade L80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,423.2 6,002.3 29.55 PACKER Baker 9 5/8" x 3-1/2" SLZXP Liner top packer Left in hole down 6.120 8,451.1 6,026.6 29.40 PBR Seal Bore Extension (3' space out off tag) 4.000 8,835.4 6,365.8 27.32 TANDEM WEDGE Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 2.992 8,850.0 6,378.7 27.27 NIPPLE HES 3 1/2" x 2.813" X nipple Profile (SN:) 2.813 8,860.4 6,388.0 27.23 TANDEM WEDGE Northern Solutions 3 1/2" x 9 5/8" Tandem Wedge Assembly 2.992 8,875.0 6,400.9 27.18 NIPPLE HES 3 1/2" x 2.813" X nipple Profile (SN:) 2.813 8,894.5 6,418.3 27.10 NIPPLE HES 3 1/2" x 2.813" X nipple Profile W/ RHC Plug Installed (SN: 2727A-4-8) 2.813 8,895.4 6,419.1 27.10 MULE SHOES Baker 3 1/2" x 9 5/8" Poorboy Overshot (6.77' Swallow) 3.640 Tubing Description TUBING WO 4.5x3.5x2.875" String Ma… 5.66 ID (in) 3.25 Top (ftKB) 8,901.1 Set Depth (ft… 8,945.3 Set Depth (TVD) (… 6,463.5 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,909.6 6,431.8 27.05 SLIDING SLEEVE BAKER CMU SLIDING SLEEVE; SEIZED IN CLOSED POSITION 12/8/2007 2.750 8,919.6 6,440.6 27.01 XO REDUCING CROSSOVER 3.5 x 2.875 2.875 8,921.4 6,442.3 27.00 SEAL ASSY BAKER GBH 80-32 LOCATOR SEAL ASSEMBLY 2.440 8,922.3 6,443.1 27.00 PACKER BAKER D PERMANENT PACKER 3.250 8,937.1 6,456.3 26.95 NIPPLE OTIS XN NO GO NIPPLE 2.250 8,944.5 6,462.9 26.92 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,901.0 6,424.1 27.08 CHEM CUT 2 3/8" Chemical cut. 6/26/2019 0.000 8,904.0 6,426.8 27.07 Cement Retainer Set Weather Cement Retainer (OAL 1.46') 9/5/2019 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,818.0 8,870.0 6,350.3 6,396.5 C-4, C-3, 1B-10 4/17/1994 4.0 RPERF 3 3/8" Hyperjet; 60 deg phasing 8,959.0 8,979.0 6,475.8 6,493.6 C-1, UNIT B, 1B -10 4/17/1994 6.0 APERF 3 3/8" Hyperjet; 60 deg phasing 9,128.0 9,138.0 6,627.5 6,636.6 A-5, 1B-10 2/4/1982 4.0 CMT SQZ 9,146.0 9,158.0 6,643.9 6,654.7 A-4, 1B-10 2/4/1982 4.0 CMT SQZ 9,158.0 9,178.0 6,654.7 6,672.9 A-4, 1B-10 2/4/1982 4.0 CMT SQZ Frac Summary Start Date 1/21/2008 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 1/21/2008 Top Depth (ftKB) 8,818.0 Btm (ftKB) 8,870.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 1B-10, 10/11/2019 10:33:35 AM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 APERF; 8,959.0-8,979.0 SOS; 8,944.5 NIPPLE; 8,937.1 PACKER; 8,922.3 SEAL ASSY; 8,921.4 SLIDING SLEEVE; 8,909.6 Cement Retainer; 8,904.0 CHEM CUT; 8,901.0 MULE SHOES; 8,895.4 NIPPLE; 8,894.5 NIPPLE; 8,875.0 TANDEM WEDGE; 8,860.4 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 TANDEM WEDGE; 8,835.4 PBR; 8,451.1 SBE; 8,451.7 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 Annular Fluid - Saltwater/Brine; 5,122.0-9,800.0; 7/18/2019 Annular Fluid - Saltwater/Brine; 5,122.3-8,922.3; 7/18/2019 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 Annular Fluid - Saltwater/Brine; 2,000.0-5,122.3; 7/18/2019 Annular Fluid - Saltwater/Brine; 2,000.0-5,122.3; 7/18/2019 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 Annular Fluid - Diesel; 23.6- 2,000.0; 7/19/2019 Annular Fluid - Diesel; 23.6- 2,000.0; 7/19/2019 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD KB-Grd (ft) 31.99 Rig Release Date 12/13/1981 1B-10 ... TD Act Btm (ftKB) 9,403.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292065600 Wellbore Status PROD Max Angle & MD Incl (°) 59.73 MD (ftKB) 6,300.00 WELLNAME WELLBORE1B-10 Annotation Last WO: End Date 6/28/2019 H2S (ppm) 40 Date 8/12/2016 Comment Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,859.1 2,509.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,292.0 10/9/2019 2 5,127.3 3,810.4 Camco MMG 1 1/2 GAS LIFT OV RK 0.188 10/9/2019 3 6,733.2 4,654.6 Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 4 7,645.5 5,342.0 Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 5 8,401.1 5,983.1 Camco MMG 1 1/2 GAS LIFT DMY RK 7/18/2019 Notes: General & Safety End Date Annotation 1/29/1998 NOTE: WAIVERED WELL: IA x OA ANNULAR COMMUNICATION 7/31/2019 NOTE: View Schematic w/ Alaska Schematic10.0 1B-10, 10/11/2019 10:33:36 AM Vertical schematic (actual) PRODUCTION; 28.3-9,358.4 CMT SQZ; 9,158.0-9,178.0 CMT SQZ; 9,146.0 ftKB CMT SQZ; 9,146.0-9,158.0 CMT SQZ; 9,128.0 ftKB CMT SQZ; 9,128.0-9,138.0 APERF; 8,959.0-8,979.0 SOS; 8,944.5 NIPPLE; 8,937.1 PACKER; 8,922.3 SEAL ASSY; 8,921.4 SLIDING SLEEVE; 8,909.6 Cement Retainer; 8,904.0 CHEM CUT; 8,901.0 MULE SHOES; 8,895.4 NIPPLE; 8,894.5 NIPPLE; 8,875.0 TANDEM WEDGE; 8,860.4 NIPPLE; 8,850.0 RPERF; 8,818.0-8,870.0 FRAC; 8,818.0 TANDEM WEDGE; 8,835.4 PBR; 8,451.1 SBE; 8,451.7 PACKER; 8,423.2 GAS LIFT; 8,401.1 GAS LIFT; 7,645.5 Annular Fluid - Saltwater/Brine; 5,122.0-9,800.0; 7/18/2019 Annular Fluid - Saltwater/Brine; 5,122.3-8,922.3; 7/18/2019 GAS LIFT; 6,733.2 GAS LIFT; 5,127.3 Annular Fluid - Saltwater/Brine; 2,000.0-5,122.3; 7/18/2019 Annular Fluid - Saltwater/Brine; 2,000.0-5,122.3; 7/18/2019 GAS LIFT; 2,859.1 SURFACE; 30.3-2,547.0 SSSV ; 1,799.4 Annular Fluid - Diesel; 23.6- 2,000.0; 7/19/2019 Annular Fluid - Diesel; 23.6- 2,000.0; 7/19/2019 CONDUCTOR; 31.3-80.0 HANGER; 23.6 KUP PROD 1B-10 ... WELLNAME WELLBORE1B-10 !"# $%&'#()*+, !"# )-./01234/.+!5!5 +!5 ,!56+) !"# #7434/..89+!:! 342 4/;<= #743<>%<43&%743+)!? #743#+!?:,'?= @)A&&/4+++ !"#:+)'?= #743%3 8$B43.C1++ ,!"# #110&3 8++ +!"# C419+ ,!? <401033/&/41 #743*/2/44B4+ ,!"# $+() #743?%743+ !"# $1.AA&&/4+ )!"# + <+,.C4 )+!? .2&430.D> +! +!? ))+ A+,.C4 !? , @, .C4+,!? .2&430. +++!++,!? %3&.42"$%++!? !"#$% E) ) <+,#.4%&4E+$?: !/=E9!1/<41CE, #341C3*&&4338E#341C3<;4341E@+A&&/4 4/; .2&430. + ! + !? &0<43++)!? ?5,,,!? #,< WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 1B-10L1Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2200320KUPARUK RIVER, KUPARUK RIV OIL - 490100NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberYes4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesDirectional plan view & wellbore profile included.8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NAConductor set for KRU 1B-1018Conductor string providedNASurface casing set in KRU 1B-1019Surface casing protects all known USDWsNASurface casing set and fully cemented20CMT vol adequate to circulate on conductor & surf csgNA21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented slotted liner22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis performed; major risk failure 1B-16 in zone26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYesMax formation pressure is 3456 psig(10.0 ppg EMW);will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2819 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesH2S measures required33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoWells on 1B-Pad are H2S-bearing. H2S measures required.35Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate3/25/2020ApprVTLDate3/31/2020ApprDLBDate3/24/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate'76JMP 4/1/2020JLC 4/1/2020