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Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/01/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 6/1/2023. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 6/1/2023. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/01/2023Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateL-2072210815002923702003.371.31/23/2023123/1/2023L-2312230105002923746003.003.0-393/27/2023M-111810575002920589002.602.6-105/29/2023M-311920325002922256001.501.5-165/29/2023M-331941165002922504001.301.3-145/29/2023N-171830095002920898001.201.2-115/30/2023N-18A2081755002920906010.500.5-65/30/2023N-21A1961965002921342011.001.0-85/30/2023N-272071045002923365000.500.5-45/30/2023N-292141105002923521002.302.3-245/30/2023N-31215175500292356000-0--205/30/2023V-2342220045002923707006.3210.91/23/2023243/1/2023W-2412221545002923741002.502.5-263/1/2023Z-121891025002921977000.700.7-45/23/2023Z-34212061500292346900-0--155/27/2023Z-402111735002923462000.700.7-65/27/2023Z-46A2052035002923280010.500.5-35/23/2023Z-502120015002923463000.500.5-35/27/2023Z-662121955002923482000.700.7-85/27/2023Z-116211124500292345500-0--175/27/2023Z-210204181500292322600-0--125/27/2023Z-2292221045002923726003.8361.23/5/2023363/27/2023V-2342220045002923707006.3210.91/23/2023243/1/2023 DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23707-00-00Well Name/No.PRUDHOE BAY UNIT V-234Completion Status1-OILCompletion Date3/19/2022Permit to Drill2220040OperatorHilcorp North Slope, LLCMD11832TVD4596Current Status1-OIL8/19/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, DGR, ABG, ESR, ADR MD & TVD, same PB1 & PB2NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF4/5/20225172 11795 Electronic Data Set, Filename: PBU V-234 ADR Quadrants All Curves.las36443EDDigital DataDF4/5/2022150 11832 Electronic Data Set, Filename: PBU V-234 LWD Final.las36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Geosteering EOW Plot.emf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Geosteering EOW Plot.pdf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Geosteering End of Well Report.pdf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Post-Well Geosteering X-Section Summary with PBs.pdf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Post-Well Geosteering X-Section Summary.pdf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Geosteering EOW Plot150.tif36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Geosteering EOW Plot200.tif36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 Geosteering EOW Plot300.tif36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final MD.cgm36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final TVD.cgm36443EDDigital DataDF4/5/2022 Electronic File: V-234 - Definitive Survey Report.pdf36443EDDigital DataDF4/5/2022 Electronic File: V-234 - DSR GIS.txt36443EDDigital DataFriday, August 19, 2022AOGCC Page 1 of 4PB1PB2PBU V-234 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23707-00-00Well Name/No.PRUDHOE BAY UNIT V-234Completion Status1-OILCompletion Date3/19/2022Permit to Drill2220040OperatorHilcorp North Slope, LLCMD11832TVD4596Current Status1-OIL8/19/2022UICNoDF4/5/2022 Electronic File: V-234 - DSR.txt36443EDDigital DataDF4/5/2022 Electronic File: V-234 - Final Surveys.xlsx36443EDDigital DataDF4/5/2022 Electronic File: V-234_DSR Actual_Plan.pdf36443EDDigital DataDF4/5/2022 Electronic File: V-234_DSR Actual_VSec.pdf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final MD.emf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final TVD.emf36443EDDigital DataDF4/5/2022 Electronic File: PBU_V-234_ADR Image.dlis36443EDDigital DataDF4/5/2022 Electronic File: PBU_V-234_ADR Image.ver36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final MD.pdf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final TVD.pdf36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final MD.tif36443EDDigital DataDF4/5/2022 Electronic File: PBU V-234 LWD Final TVD.tif36443EDDigital DataDF4/5/20225172 6970 Electronic Data Set, Filename: PBU V-234PB1 ADR Quadrants All Curves.las36444EDDigital DataDF4/5/2022150 7007 Electronic Data Set, Filename: PBU V-234PB1 LWD Final.las36444EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final MD.cgm36444EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final TVD.cgm36444EDDigital DataDF4/5/2022 Electronic File: V-234PB1 - Definitive Survey Report.pdf36444EDDigital DataDF4/5/2022 Electronic File: V-234PB1 - DSR GIS.txt36444EDDigital DataDF4/5/2022 Electronic File: V-234PB1 - DSR.txt36444EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final MD.emf36444EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final TVD.emf36444EDDigital DataDF4/5/2022 Electronic File: PBU_V-234PB1_ADR Image.dlis36444EDDigital DataDF4/5/2022 Electronic File: PBU_V-234PB1_ADR Image.ver36444EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final MD.pdf36444EDDigital DataFriday, August 19, 2022AOGCC Page 2 of 4PBU V-234PB1 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23707-00-00Well Name/No.PRUDHOE BAY UNIT V-234Completion Status1-OILCompletion Date3/19/2022Permit to Drill2220040OperatorHilcorp North Slope, LLCMD11832TVD4596Current Status1-OIL8/19/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final TVD.pdf36444EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final MD.tif36444EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB1 LWD Final TVD.tif36444EDDigital DataDF4/5/20225172 10764 Electronic Data Set, Filename: PBU V-234PB2 ADR Quadrants All Curves.las36445EDDigital DataDF4/5/2022150 10802 Electronic Data Set, Filename: PBU V-234PB2 LWD Final.las36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final MD.cgm36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final TVD.cgm36445EDDigital DataDF4/5/2022 Electronic File: V-234PB2 - Definitive Survey Report.pdf36445EDDigital DataDF4/5/2022 Electronic File: V-234PB2 - DSR GIS.txt36445EDDigital DataDF4/5/2022 Electronic File: V-234PB2 - DSR.txt36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final MD.emf36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final TVD.emf36445EDDigital DataDF4/5/2022 Electronic File: PBU_V-234PB2_ADR Image.dlis36445EDDigital DataDF4/5/2022 Electronic File: PBU_V-234PB2_ADR Image.ver36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final MD.pdf36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final TVD.pdf36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final MD.tif36445EDDigital DataDF4/5/2022 Electronic File: PBU V-234PB2 LWD Final TVD.tif36445EDDigital DataFriday, August 19, 2022AOGCC Page 3 of 4PBU V-234PB2 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23707-00-00Well Name/No.PRUDHOE BAY UNIT V-234Completion Status1-OILCompletion Date3/19/2022Permit to Drill2220040OperatorHilcorp North Slope, LLCMD11832TVD4596Current Status1-OIL8/19/2022UICNoCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud 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 HISTORYDate CommentsDescriptionCompletion Date:3/19/2022Release Date:1/31/2022Friday, August 19, 2022AOGCC Page 4 of 4M. Guhl8/19/2022 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov -XQH 0U6WDQ*ROLV 6HQLRU2SHUDWLRQV0DQDJHU +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'ULYH6XLWH $QFKRUDJH$. 5H 'HIHDWHG6DIHW\9DOYH6\VWHP 3%89 37' 'HDU0U*ROLV 7KH$2*&&ZLWQHVVHGSHUIRUPDQFHWHVWLQJRIZHOOVDIHW\YDOYHV\VWHPVDW3%89SDGRQ$SULO :HOO9ZDVIRXQGZLWKWKHVDIHW\YDOYHV\VWHP¶VORZSUHVVXUHGHWHFWLRQGHYLFH GHIHDWHGSUHYHQWLQJWKHDXWRPDWLFFORVXUHRIWKHVXUIDFHVDIHW\YDOYH2Q$SULO+LOFRUS SURYLGHGDOHWWHUGHVFULELQJWKHHYHQWGHWDLOVRILWVLQWHUQDOLQYHVWLJDWLRQFDXVDOIDFWRUVDQGVHYHQ DFWLRQV WR SUHYHQW UHFXUUHQFH 2Q -XQH +LOFRUS SURYLGHG DQ XSGDWH LGHQWLI\LQJ DOO FRUUHFWLYHDFWLRQVDVFRPSOHWHG$2*&&KDVUHYLHZHGWKHLQIRUPDWLRQSURYLGHGDQGLVVDWLVILHG ZLWK+LOFRUS¶VUHVSRQVHWRWKHGHIHDWHGZHOOVDIHW\YDOYHV\VWHPDW3%89 6LQFHUHO\ -HUHP\03ULFH &RPPLVVLRQHU&KDLU FF 2OLYHU6WHUQLFNL+LOFRUS ROLYHUVWHUQLFNL#KLOFRUSFRP Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.23 14:11:47 -08'00' +LOFRUS1RUWK6ORSH//& 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Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 51.0' BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" X-52 192' 1856' 4352' 7" L-80 4352' 4-1/2" L-80 4596' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9-5/8" w/ Metal Expandable Packers (Uninflated) L-80 12-1/4" 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, Uncemented Tieback LinerTieback TUBING RECORD Uncemented Screen Liner 4951'4-1/2" 12.6# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 5010' 11800' Stg 2 L - 444 sx / T - 274 sx 4348' 42" x 24" 12.75# 26' 1958' Stg 1 L - 425 sx / T - 412 sx 8-1/2" 8 yds Concrete STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 3/19/2022 4798' FSL, 1935' FEL, Sec. 11, T11N, R11E, UM, AK 2626' FNL, 1885' FWL, Sec. 01, T11N, R11E, UM, AK 222-004 Schrader Bluff Oil Pool, Orion Dev Area 77.9' 11798' / 4596' Prudhoe Bay Field / HOLE SIZE AMOUNT PULLED 50-029-23707-00-00 PBU V-234 590366 5970043 2226' FNL, 1522' FEL, Sec. 11, T11N, R11E, UM, AK CEMENTING RECORD 5968304 SETTING DEPTH TVD 5973225 BOTTOM TOP 25' 26' CASING WT. PER FT.GRADE 29# 590802 594145 TOP SETTING DEPTH MD 25' 26' Per 20 AAC 25.283 (i)(2) attach electronic information 40# 5019' 1856' 26' DEPTH SET (MD) 4862' / 4270' PACKER SET (MD/TVD) 129.5# 47# 192' 1958' 5182' Gas-Oil Ratio:Choke Size: PB1: 6664' - 7007' 45 Bbls Cement Water-Bbl: PRODUCTION TEST Not on Production Date of Test: Flow Tubing Oil-Bbl: 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 N/A 4-1/2" 100 Micron Screens 3/17/2022 5257' - 5455' 4430' - 4476' 5664' - 6142' 4515' - 4536' 6508' - 7864' 4522' - 4562' 7892' - 8932' 4563' - 4590' 8960' - 10403' 4589' - 4579' 10431' - 11756' 4579' - 4596' PB1: ROP, AGR, DGR, ABG, ESR, ADR MD & TVD PB2: ROP, AGR, DGR, ABG, ESR, ADR MD & TVD A: AROP, AGR, DGR, ABG, ESR, ADR MD & TVD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 3/15/2022 3/1/2022 ADL 028240 00-001 1803' / 1710' N/AN/A None 11832' / 4596' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment G By Meredith Guhl at 9:04 am, Apr 07, 2022 Completion Date 3/19/2022 MDG RBDMS 4/7/2022 MDG DSR-4/11/22MGR18AUG2022DLB 04-27-2022 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 54' 54' 1857' 1764' Top of Productive Interval 5280' 4435' 1687' 1608' 2809' 2612' 3596' 3284' 4611' 4110' 5280' 4435' 5714' 4521' SB OBa 5714' 4521' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and 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. Authorized Name: Monty Myers Authorized Title: Drilling Manager Schrader Bluff OA Schrader Bluff OBa Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Ugnu MB SV5 SV1 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. 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). 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 Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, 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: Ugnu 3 LOT / FIT Data Sheet, Drilling and Completion Reports, Casing and Cement Report, Definitive Directional Surveys, Wellbore Schematic Signature w/Date: 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. INSTRUCTIONS 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). 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. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 4.6.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.04.06 15:03:50 -08'00' Monty M Myers CASING AND LEAK-OFF FRACTURE TESTS Well Name:PBU V-234 Date:3/8/2022 Csg Size/Wt/Grade: Supervisor:Barber/Montague Csg Setting Depth:5180 TMD 4410 TVD Mud Weight:9.5 ppg LOT / FIT Press =574 psi LOT / FIT =12.00 ppg Hole Depth =5190 md Fluid Pumped=1.1 Bbls Volume Back =0.8 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->04 ->00 ->4 141 ->544 ->8 296 ->10 137 ->12 415 ->15 337 ->16 477 ->20 556 ->20 506 ->25 745 ->24 535 ->30 949 ->28 575 ->35 1156 -> ->40 1373 -> ->45 1591 -> ->50 1813 -> ->55 2049 -> ->60 2278 -> ->69 2689 Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0.5 566 ->0 2689 ->1 562 ->1 2683 ->2 556 ->2 2677 ->3 552 ->3 2672 ->4 547 ->4 2670 ->5 544 ->5 2667 ->6 540 ->10 2660 ->7 537 ->15 2653 ->8 535 ->20 2649 ->9 532 ->25 2645 ->10 530 ->30 2641 -> -> -> -> -> -> 9 5/8" 47#/40# L-80 0 4 8 12 16 20 24 28 0 5 10 15 20 25 30 35 40 45 50 55 60 69 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 1020304050607080Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 566562556552547544540537535532530 268926832677267226702667 2660 2653 2649 2645 2641 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 2/27/2022 PJSM Stomp sub over V-234. Center sub and shim as needed. Set matt boards. Spot and level Catwalk. PJSM Cont spot Pipe shed, pit and gen mods. Release AES trucks at 14:15. PJSM Connect interconnects R/U steam, H2O & air lines. Charge steam lines and check for leaks. Thaw out steam heaters in cellar. R/U Mezz kill lines. Reinstall ODS cellar stairs. Assist welder in pits with patching hole in possum belly and frame of shaker #1. PJSM Scope up derrick, run in derrick pins. R/U upper section lights, WT bucket & Geronimo line. Bridle down. PJSM Set stack on diverter tee. Line up tee for diverter section. Install knife valve and diverter section under pipe shed. SIMOPS Cont welding in pits. Take off shaker #1 motor and wire wheel on mount and under motor due to debris. Re assy MP #2. Spot cutting box, break shack & enviro. R/U rig tongs and floor. Dismantle centrifuges for bowl removal. PJSM Cont installing diverter section. Trq speed head on well head. Install chain binders and secure. Weld 4" cam loc nipple on drip pan. Prep shaker motor and mounts for inspection. Process 5" D.P. in pipe shed. Cont prep centrifuges for bowl removal. PJSM C/O 4" XT39 saver sub to 5" NC50. C/O grabber box dies and bell guide. Adjust links in drag chain and tighten. Install 2ea 4" ball valves on conductor. Cont to process pipe in shed. Daily Disposal to G&I = 38 bbls, total = 38 bbls. Daily H2O from Lake 2 = 290 bbls total = 490 bbls. Daily Metal: 0 lb. Total Metal 0 lb. 2/28/2022 PJSM Cont working on rig acceptance. Install trip nipple flange and trip nipple with spare air boots. Install short mouse hole. SIMOPS Crane on location 07:00. Crane in 16" Diverter sections W/ pedestals. (215') Crane out Centrifuge #1 Motor and Bowl Assy, Centrifuge #2 Bowl Assy. Crane in new Bowl Assy and Motor for centrifuges. Crane released at 10:30. Install hole fill line on stack. PJSM Cont working on rig acceptance check list. Perform pre spud derrick inspection. Cont installing centrifuge motor & bowl assy.. Perform monthly EAM inspection on top drive. C/O actuator on IBOP. Bring on 580 bbls 8.85 ppg Spud Mud into pits. PJSM Disconnect knife valve and install short mouse, close annular. P/U 5" 19.5# S-135 NC50 D.P. (200 jnts), 17 ea 5" HWDP 49.5# S-135 NC50 & 6.5" SLB Hydra Jar, rack back in derrick via mouse hole. SIMOPS reassemble centrifuges and test, good. Shim Motor on shakers. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Checked PVT sensor. Rig accepted at 18:00 hrs. Obtain RKB Ann 11.99' GL 26.9' Perform Annular closure 8 sec, knife 7 sec. Koomey draw drown Initial System 2,950 PSI, after System 1,950 PSI, 200 PSI increase 17 Sec, full charge 56 sec. Nitrogen 6 bottle average 2,333 PSI. Witness waived by AOGCC rep Brian Bixby. PJSM Cut & slip drilling line. ACCUM TM 39572. Cut 10 wraps (63') 545' left on spool. Removed dead man and spool on new line to drum. Trq dead man 85 ft/lb. P/U blocks and remove hanging line. Grease crown and calibrate blocks. PJSM Stage Kymera Hybrid Bit and X/O on rig floor. Install surface bushings. Prep ODS tongs. PJSM Inspect cradle on top drive, good. PJSM Pre spud meeting with all personnel and for P/U BHA. Daily Disposal to G&I = 0 bbls, total = 38 bbls. Daily H2O from Lake 2 = 290 bbls total = 780 bbls. Daily Metal: 0 lb. Total Metal 0 lb. 3/1/2022 P/U M/U 12.25” Kymera Hybrid (0.8399 TFA) to 8” TerraForce 1.5° motor. Kelly up to 1 stand 5” HWDP. Flood all lines W/ spud mud and check for leaks, good. PT surface lines to 3,000 psi, good. Wash & ream 20” conductor to 197’ and drill to 220’ MD. 325 gpm, 285 psi, 30 rpm, Trq 750 ft/lb, F/O 50%. WOB 1-2k ROP 60- 100 ft/hr. Tag fill at 61’ MD. Encountered 60-100 bph dynamic losses exiting the conductor at 197’ MD, lost about 37 bbls. Jet flow line as needed and during connections. Clearing drag chain due to overloading of gravel as needed. P/U 47k SLK 46k ROT 46k CBU at 220' MD BROOH to 170' MD Clear drag chain of gravel. 325 gpm, 285 psi, 30 rpm, Trq 750 ft/lb, F/O 50%.Pull Bit and mtr to floor and inspect same. No damage to bit (cleared 2 rocks stuck in cones). Clean and clear rig floor. Mob MWD tools to floor. M/U 12-1/4" Kymera K5M633 (.8399 TFA), 1.5° 8" Terra Force 4/5 lobe:5.3 stg mtr. M/U GWD, DM. 62.37° RFO GWD, 160.4° RFO Mtr. M/U MWD, TM, Download MWD. Continue M/U 2x NM flex DC's, BN XO, 6x 5" HWDP, Jars, 11x 5" HWDP. Total length of BHA = 720.62'. Drill 12.25" surface hole F/ 220' - T/ 255' MD. 450 gpm, 780 psi, 1-2k WOBB, 30 RPM, 1k Tq on/off, 55% F/O. P/U 54k, S/O 51k, ROT 54k. Saw heavy gravel first 250'. Packed off drag chain 1x. Cleared without issue. Slide/ Rot 12.25" surface hole F/ 255' - T/ 718' MD, 717' TVD. total 462' arop 77' 450 gpm, 1080 psi, 2-10k WOB, 30-40 RPM, 1.2k Tq on/off, 65% F/O. P/U 72k, S/O 68k, ROT 70k. KOP @ 407' MD (WP10). Dynamic losses 1-5 bph when drilling operations resumed. Build 4°/100'. Slide/ Rot 12.25" Surface Hole F/ 718' to 1,226' MD (1,201' TVD) Total 508’ (AROP 84.7’) 500 GPM, 1,450 psi 40-60 RPM, TRQ on 3-4k, TRQ off 1- 2k, F/O 66%, WOB 5-12k. ECD 10.2 W 9.25 MW.. Max Gas 20u. P/U 78K, SLK 76K, ROT 76K. Jet flowline every other stand. Back ream full stands. Cont build 4°/100 as per plan.. Dynamic loss 1-5 bph. Slide/ Rot 12.25" Surface Hole F/ 1,226' to 1,861' MD (1,767' TVD) Total 635’ (AROP 105.8’) 400-500 GPM, 1,325 psi 60 RPM, TRQ on 4-5k, TRQ off 3-4k, F/O 61%, WOB 5-8k. ECD 10.6. W/ 9.4 MW. Max Gas 22u. P/U 94K, SLK 81K, ROT 82K. Jet flowline every other stand. Back ream full stands. At ~1.720' MD control flow due to shakers running over. End build 4°/100 as per WP10 at 1,238' MD. Target 25° inc 200° az for tangent. Clean MWD survey at 1,238' MD. Maintenance slide as needed. Pre treat Hydrates staring at 1,400' MD W/ 1 ppb DrilTreat. Dynamic loss 1-5 bph. Distance to WP10: 11.25', 11.24' High, 0.57' Right Daily Disposal to G&I = 741 bbls, total = 779 bbls. Daily H2O from Lake 2 = 720 bbls total = 1500 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 87 bbls. Total Surface Loss: 87 bbls. 3/2/2022 Slide/ Rot 12.25" Surface Hole F/ 1861' - T/ 2499' MD (2344' TVD) Total 638’ (AROP 106’) 500 GPM, 1380 psi, 80 RPM, TRQ on 5.6k, TRQ off 4.5k, F/O 65%, WOB 5-8k. ECD 10.8. W/ 9.7 MW. Max Gas 172u. P/U 109K, S/O 85K, ROT 96K. Jet flowline every other stand. Back ream full stands. Decision made to top set surface casing above Schrader. Begin directional work as per new WP11 @ ~2434' MD. Permafrost logged @ 1857' MD / 1764' TVD Slide/ Rot 12.25" Surface Hole F/ 2499' - T/ 3133' MD (2887' TVD) Total 634’ (AROP 106’) 500 GPM, 1645 psi, 80 RPM, TRQ on 6.7k, TRQ off 5k, F/O 59%, WOB 5-8k. ECD 10.6 W/ 9.7 MW. Max Gas 122u. P/U 118K, S/O 89K, ROT 103K. Jet flowline every other stand. Back ream full stands. Observed hydrates breaking out at surface 3008' MD / 2784' TVD. Slide/ Rot 12.25" Surface Hole F/ 3133'- T/ 3706' MD (3373' TVD) Total 573’ (AROP 96’) 500 GPM, 1735 psi, 80 RPM, TRQ on 8-9K, TRQ off 7-8K, F/O 48%, WOB 5-14k. ECD 10.3 w/ 9.6 MW. Max Gas 262u. P/U 135K, S/O 90K, ROT 111K. Back ream full stands. Start 5°/100' build and turn at 3578'. Observe oil on shakers at 3260' Slide/ Rot 12.25" Surface Hole F/ 3706'- T/ 4035' MD (3658' TVD) Total 329’ (AROP 55’) 500 GPM, 1760 psi, 80 RPM, TRQ on 10K, TRQ off 9K, F/O 55%, WOB 5-16k. ECD 10.3 w/ 9.6 MW. Max Gas 124u. P/U 153K, S/O 96K, ROT 114K. Back ream full stands. Slide for 5°/100' build and turn. Daily Disposal to G&I = 1031 bbls, total = 1810 bbls Daily H2O from Lake 2 = 1210 bbls total = 2710 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 0 bbls. Total Surface Loss: 87 bbls. Distance to WP#11: 15.11', 12.46'High, 8.55'Right. 3/1/2022Spud Date: Well Name: Field: County/State: PBW V-234 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 50-029-23707-00-00API #: 3/3/2022 Continue Drlg 12.25" Surface Hole F/ 4035'- T/ 4407' MD (3965' TVD) Total 372’ (AROP 62’) 500 GPM, 1825 psi, 80 RPM, TRQ on 11K, TRQ off 9K, F/O 55%, WOB 5-12k. ECD 10.6 w/ 9.6 MW. Max Gas 72u. P/U 155K, S/O 101K, ROT 122K. Back ream full stands. Slide for 5°/100' build and turn WP11. Begin adding lubes @ ~4200' MD to help slides as per DD request. No notable hydrates breaking out during this drilling interval. Continue Drlg 12.25" Surface Hole F/ 4407'- T/ 4828' MD Total 421’ (AROP 70’) 500 GPM, 1765 psi, 80 RPM, TRQ on 11-12K, TRQ off 10-11K, F/O 51%, WOB 5-14k. ECD 10.3 w/ 9.6 MW. Max Gas 20u. P/U 172K, S/O 100K, ROT 126K. Back ream full stands. Slide for 5°/100' build and turn WP11. Continue Drlg 12.25" Surface Hole F/ 4828'- T/ 5150' MD (4404' TVD) Total 322’ (AROP 54’) 500 GPM, 1900 psi, 80 RPM, TRQ on 12-14K, TRQ off 10-13K, F/O 51%, WOB 7-16k. ECD 10.2 w/ 9.6 MW. Max Gas 183u. P/U 175K, S/O 103K, ROT 126K. Back ream full stands. Slide for 5°/100' build and turn WP11. Cont. drilling from 5150' to casing point at 5190' (4412' TVD) Total 40’ (AROP 27’) 500 GPM, 1725 psi, 80 RPM, TRQ on 16K, TRQ off 12-15K, F/O 52%, WOB 7-12K. ECD 10.3 w/ 9.6 MW. Max Gas 22u. P/U 167K, S/O 102K, ROT 125K. Back ream full stands. Slide for 5°/100' build/turn WP11. Obtain final survey. BROOH from 5190' to 5045', 500 gpm 1700 psi, 80 rpms 15-16Kft-lbs, Max gas 22u. P/U 172K, S/O 100K, ROT 125K Pump high vis sweep (no increase, strung out) and circulate additional bottoms up, 500 gpm 1625 psi, 80 rpms 12-13Kft-lbs. Monitor well, static. RIH on elevators to 5190' with no issues. Downlink to set GWD in out-run mode. BROOH from 5190' to 4837' at 500 gpm 1585 psi, 80 rpms 10- 15Kft-lbs. Max gas 22u. P/U 172K, S/O 97K, ROT 124K. Pull spead 5-15 fpm as hole dictates Daily Disposal to G&I = 1321 bbls, total = 3131 bbls. Daily H2O from Lake 2 = 1130 bbls total = 3840 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 0 bbls. Total Surface Loss: 87 bbls. Distance to WP#11: 12.74', 2.51' high, 12.5' left. 3/4/2022 Cont BROOH from 4837' to 1900' 500 gpm, 1370 psi, 40 rpms, 6Kft-lbs. max gas 22u. P/U 105K, S/O 78K, ROT 86K. Pull 15-30 fpm as hole dictates. Saw 5-8k tq spikes throughout slide intervals but clean thru tangent. Reduced RPM from 80 to 60 once below 40° Inc and again reduced RPM from 60 to 40 once below 20° Inc. Cont. to BROOH from 1900' to 720' at 500 gpm, 1230 psi, 20-40 rpms, 4-8Kft-lbs. P/U 72K, S/O 72K, ROT 82K. Pull 15-30 fpm as hole dictates. Attempt to POOH at HWDP, pull 20K over. Cont BROOH from 720' to 281' at 375 gpm, 600 psi, 15 rpms, 1-6Kft-lbs. Blow down TD and Geo-span. L/D BHA: 2 flex collars. Download MWD. L/D remaining BHA. Bit grade1-1-CT-A-E-I-NO-TD Clean and clear rig floor of BHA components. Swing ST-80 into storage position. R/D hydraulic elevators. Jet flow line. Rig up Volant, bail extensions and side door elevators. Bring 60 centralizers to rig floor. Rig up Weatherford power tongs. Install top hat on float in shed as per HES. RIH with 9-5/8", L-80, TXP casing to 656'. M/U shoe track and Bakerlok. Check floats - good. TQ connections to 20,960 ft-lbs. Fill casing every 5 joints, top off ever 10. P/U 59K, S/O 50K. Install centralizers every joint for first 25 joints as per tally. Cont. to RIH with 9-5/8, 40#, L-80 casing from 656' to 1964'. At 1200' set down in stack, drain stack and adjust stack. Set down 15K at 1887', 40K overpull. Establish circulation staging pumps up to 5.5 bpm 200 psi, rotary 5-10 rpms 6-12Kft-lbs (limiter set at 12K). Wash and ream down to 1905', with no further progress, stalling out at 12Kft-lbs. Clean pick up weight. Shut rotary down and continue to work pipe down to 1964', setting down up 45K with minimum overpulls. Daily Disposal to G&I = 632 bbls, total = 3763 bbls. Daily H2O from Lake 2 = 770 bbls total = 4610 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 55 bbls. Total Surface Loss: 142 bbls. 3/5/2022 Cont. to RIH with 9-5/8, TXP 40#, L-80 casing from 1964' 3827' MD. Worked down from 1964' to 2240' MD with 2-6 bpm, 109k up, 76k dn. Maintain good circulation while working pipe with minimal psi spikes. Observed small gravel and wood splinters back at shakers before tripping in clean, Continue RIH with 9-5/8" 40# TXP and crossed over to 47# VAM 21 from 1964' to final set depth of 5180' MD after making up stage tool. Tripped thru tangent and last build/turn section without issue. Fill every 5 and washed down every 10th jt. 42 bbl loss for casing run. TXP 20.9K ft- bs Tq Vam 21 connections to 31.5K ft-lbs. Bakerlok jts above and below ES cementer. Verify (6) pins (~3300 psi). HES rep onsite for M/U. P/U 253k, S/O 133k. Install a total of 56 Bow Spring centralizer as per detail (floating). RIH @ 20-30 fpm. Break circulation and stage up in 1 bbls increment to 6.5 bpm ICP 335 psi, FCP 300 psi. Rotate 1-3 rpms 15Kft-lbs (limiter set at 15Kft-lbs) reciprocating pipe. Shut down pumps, B/D top drive and shut IBOP's. Line up and circulate through cement line. Sim Ops: Rig down casing equipment, power tongs, elevators, and bail extensions. Clean and clear rig floor. Prep pits. Spot and rig up cementers. Perform 1st stage cement job HES pump: 5 bbls water 2 bpm, 120 psi. PT lines 1000/4000 psi - good. 67 bbls 10.0 ppg tuned spacer 3.7 bpm, 200 psi with 4# red dye and 5# polyflake in first 10 bbls. Drop bypass plug. 178 bbls 12 ppg type I/II lead cement (yield 2.347) at 4.3 bpm, 280 psi. 85 bbls 15.8 ppg type I/II tail cement (yield 1.156) at4.3 bpm, 720 psi. Drop shut off plug. Displace with 20 bbls water from HES at 5.3 bpm, 287 psi. Rig displace 203.5 bbls 9.6 ppg spud mud at 7.5 bpm, 420 psi. HES displace 80 bbls 9.4 ppg Tuned spacer (10 bbls below, 70 bbls above ES cementer) Rig continue displacement with 79.3 bbls (calculated 74.5 bbls + 1/2 shoe track) at 4 bpm, 790 psi. Slow to 2 bpm with calc 10 bbls to go. With calculated 1.4 bbls left to go observe pressure start to drop down to 550 psi. Did not bump the plug. Shut down and observe pressure bleed to 100 psi. Check floats - observe air, no mud. Consult with town swap mud pump and pump additional 1/2 shoe track at 2 bpm 550 psi increasing to 3 bpm 790 psi. Did not bump plug. Does not appear to be pumping past the plug with lower pressures and air observed in line. Discuss with town and pump 1/2 shoe track at 4 bpm 840 psi. Did not bump. Check floats - good. Break out of Volant and drop free falling opening bomb. No losses during cement job. CIP 23:50. Rotated 1-3 rpms and reciprocated throughout job until displacing with spacer when string got sticky. Allow opening bomb to fall for 30 minutes. Bring pumps on at 1 bpm and observe tool shift open at 480 psi. Stage pumps up to 6 bpm, 375 psi. Observe all spacer and 50 bbls cement at surface at bottoms up. Cont. circulating occasionally varying rates 3-10 bpm to break down any potential channeling for 5 x BU, then 6 bpm, 247 psi, dumping 100 additional bbls of clobbered up, contaminated mud. Sim Ops: go through mud pump 1, observe thick 'jellied' mud in pump. Prep for second stage cement job. Daily Disposal to G&I = 575 bbls, total = 4338 bbls. Daily H2O from Lake 2 = 200 bbls total = 4810 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 52 bbls. Total Surface Loss: 194 bbls. 3/6/2022 Continue circulating and conditioning mud while WOC from 1st stage. Circ @ 6 bpm, 320 psi, 23% flow out via HES ES stage tool @ 1973' MD. Surge rates to 10 bpm once an hour for 2-5 min to help mitigate severe channeling and clear thick mud from wellbore (effective). Wet lines w/ 5 bbls H2O (HES). Pump 2nd stage cement job as follows: 60 bbls 10.0 ppg Tuned spacer w/ 4# red dye & 5 lb/bbl poly flake (1st 10 bbls) 3.5 bpm, 125 psi. Mix & Pump 228 bbls (444 sx) 10.7 ppg ArcticCem Lead cmt, 2.883 yld, 4.5 bpm, FCP 300 psi. Observe spacer at surface at 210 bbls lead cement pumped. Observe good 10.7 ppg lead cement back to surface at 265 bbls of lead cement pumped (284 calc). Pump 57 bbls (273 sx) 15.8 ppg HalCem Type I II Tail cmt, 1.17 yld, 4.5 bpm, FCP 360 PSI. Drop closing plug. HES 20 bbls water. Rig - MP#1 displace with 124 bbls (1999 stks / 2011 stks calc) 9.5 ppg spud mud, at 6 bpm, 480 psi then reduced to 5 bpm, 840 FCP before landing out with last 10 bbls pumped @ 3 bpm, 620 FCP. Bumped and psi up to 1930 psi (observed ES cementer shift closed @ 1545 psi). Hold 5 min and bleed off No flow. CIP @ 11:13 hrs. Dumped a total of 451 bbls mud / cmt (140 bbls cement). No losses while pumping cement job. R/D cement equipment and blowdown same. PJSM. Remove mousehole, R/U bridge crane & disconnect cross chains from stack. Disconnect accumulator lines to knife valve. Fill stack with black water & function annular. Disconnect & flush cement line then blow down. R/D Volant. R/D knife valve. Drain stack. Vac out 9.625" Csg for cut. R/D first section of diverter line. Sim-Ops: Haul off surface mud, clean pits and load 5" drill pipe into the shed. PJSM Loosen speed head and suspend stack. Set 9.625" emergency slips W/ 40k on slips as per Vault rep onsite. Cut 9.625" Csg (29.41' / 3.63' stickup). Set stack down. Johnny whack stack, jet flowline. N/D and rack back BOP stack. Sim-Ops: Cont clean pits and load 5" drill pipe into the shed. Pull trip nipple. Rack stack back on stump. Pull diverter 'T' and stage in cellar. Pick up MPD head, move stack to well center. Install MPD. Rack back on stump. Install slip lock casing spool and TQ. Install lower test plug. PT RMC seal 500/3800 psi for 10 min - good. Set tubing spool. Set DSA on spool. Install nuts. Set BOP stack on DSA. Start torqueing flanges. rig up chains. Assist beyond with rigging up 4" lines. Cont. cleaning pits. Cont. to N/U BOPE. Torque up flanges. Install drip pan, choke and kill lines. Install long mouse hole. Pressure up accumulator. Flood lines and purge air. Close MPD chokes. PT Beyond equipment 250/2000 psi. Blow down MPD lines. Remove test cap and install trip nipple. R/U to test BOPE. P/U and M/U test joint. M/U surface test manifold. fill lines and purge air. Daily Disposal to G&I = 1611 bbls, total = 5949 bbls. Daily H2O from Lake 2 = 1160 bbls total = 5970 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 0 bbls. Total Surface Loss: 194 bbls. 1964' to final set depth of 5180' MD 3/7/2022 PJSM, Fill stack and BOP equipment. Purge air and work valves. Test all BOP components with 4-1/2" and 5" test joints 250/3000 psi with 5 min hold on each. Chart and record same. No failures but did rebuild super choke prior to testing. AOGCC waived witness by Adam Earl. No failures. Koomey drawdown test - Initial 3000 psi, Drawdown psi 1500, 200 psi increase 21 secs, Full charge @ 93 secs. 6 bottle avg N2O = 2280 psi. Test gas alarms, flow paddle, pit sensors. R/D test equipment. Pull test plug and install 9" ID wear bushing. Grease blocks and top drive. Check oil levels. M/U 8.5" milltooth cleanout assy w/ 1.5° motor (plunger non ported float). RIH w/ HWDP and jars. Total length BHA = 590' Single in with 5" NC50 drill pipe F/ 590' - T/ 1957' MD. POOH racking back 5" dp to 590' MD. Pick up, drift and single in the hole from 590' to 1957'. P/U90K, S/O 75K. Drill cement and ES cementer from 1957' to 1978' at 375 gpm, 525 psi, WOB 2-5K, 40 rpms, 4Kft-lbs. P/U 90K, S/O 75K, ROT 81K. Ream through ES cementer x 3, trip through with no rotary/pumps - good. Tagged ES cementer on depth. Cont. to pick up, drift and single in the hole from 1978' to 4999', set down 8K. Pick up, fill pipe and establish circulation. Wash down at 200gpm, 550psi to 5004'. Set down 4K not washing off. Pick up and establish rotary at 30 rpms. Wash and ream down to 5004', set down 4K solid, not washing off. Circulate surface at 400 gpm, 790 psi, 30 rpms, 11-12Kft-lbs. Reciprocating pipe. Rig up testing equipment. Flood lines and purge air. PT casing to 2500 psi for 30 minutes - good, 4.2 bbls pumped, 4.1 bbls returned. Rig down and blow down lines. Wash down and drill cement, shoe track and rat hole from 5004' to 5190' at 400 gpm, 835 psi, 40 rpms, 10-12Kft-lbs, WOB 4-10K. Ream through float equipment to ensure clear. Observe remnants of free falling ES cementer opening bomb at shakers bottoms up from 5004'. Tag closing plug at 5,022', float equipment on depth (Baffle adapter 5054', Float 5095', Shoe 5179'). Daily Disposal to G&I = 228 bbls, total = 6177 bbls. Daily H2O from Lake 2 = 140 bbls total = 6110 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 0 bbls. Total Surface Loss: 194 bbls. 3/8/2022 Drill 20' of new hole from 5190' to 5210' at 450 gpm, 865 psi, 40 rpms, 10Kft-lbs. WOB 8-12K, P/U 162K, S/O 92K, ROTW 122K. Displace to 9.5 ppg Baradril-N on the fly, pump 30 bbls high vis spacer followed by drilling mud. R/U for FIT. Rack stand back to 5165'. Rig up high pressure line, TIW, and head pin. Fill lines and purge air. Shut UPR's. Pressure up to 575 psi, with 9.5 ppg mud at 4410'TVD (casing shoe). Hold pressure and for 10 min. 1.1 bbls pumped, 0.8 bbls bled back. Rig down and blow down lines. Monitor well, static. Pump 30 bbls dry job. POOH on elevators to 590'. L/D 8 joints of HW DP, rack back 3 stands and jar stand. L/D remaining BHA. Bit grad 1-1-WT-A-E-I-NO-BHA Clean and clear rig floor of BHA components. Bring up BHA #3 components M/U 8.5 RSS drilling BHA: M/U NRP and Bit to Geo-pilot. M/U ADR, PWD, DM, TM collars, inline stab. Upload MWD. Pick up and M/U 2 floats, 3 flex collars. RIH with 3 stands HWDP and Jars from derrick to 404' RIH from 404' to 5105'. Fill pipe every 2500'. Perform shallow hole pulse test and break in Geo-Pilot. P/U 163K, S/O 102K. Calculated displacement. Drain stack. Pull trip nipple. Install MPD bearing. Cut and slip drilling line. Check brakes, calibrate block height. Service rig: grease top drive, blocks and crown. Check oil levels in top drive. RIH to 5210'. Drill 8.5" hole from 5210' to 5740' (530' total, 88 fph AROP), 500 gpm, 1540 psi, 110-120 rpms, 10Kft-lbs, WOB 8-12K, ECD 10.6 ppg with 9.5 ppg mud. Max gas 650u. Start backreaming 30' at 5552'. Entered SB OA sands at 5280'. 1 concretion was drilled so far for a total of 1’ (0.2% of the lateral section). No faults have been crossed in this hole section so far. Distance to WP 11: 21.43', 6.55' High, 20.41' Left Daily Disposal to G&I = 803 bbls, total = 6980 bbls. Daily H2O from Lake 2 = 290 bbls total = 6400 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 0 bbls Total production lost: 0 bbls. Total Surface Loss: 194 bbls. 3/9/2022 Cont. drilling 8.5" hole from 5740' to 6355' (615' total, 103 fph AROP), 475 gpm, 1445 psi, 105-120 rpms, 10-12Kft-lbs, WOB 10-18K, ECD 10.6 ppg with 9.5 ppg mud. Max gas 737u. P/U 161K S/O 81K, ROT 111K. Backream full stands. Cont. drilling 8.5" hole from 6355' to 7007' (652' total, 119 fph AROP), 475 gpm, 1510 psi, 80-90 rpms, 14-15Kft-lbs, WOB 5-10K, ECD 10.7 ppg with 9.5 ppg mud. Max gas 1124u. P/U 173K S/O 69K, ROT 108K. Backream full stands. Observe lost circulation and torque stall. Pulled up with 50K overpull. Rack back stand and pull up to 6888'. Fill the annulus through kill line, took 86 bbls to fill. Line up and pump down drill string 28 bbls to fill. Cont. pumping down the drill string at 3 bpm with initial 10% returns increasing to 40% while building LCM pill. RIH to 6953' and spot 40 bbls LCM pill (25 ppb each: Baracarb 5, 25, 400) outside of bit. Pull up to 6888' and allow pill to soak. Moving pipe to ensure free and pumping every 10 minute to prevent freezing top drive. Allow pill to soak for 1 hr, new mud in route. Break circulation down hole at 2 bpm. Observe returns slowly return and increase to 60%. Continue staging pumps up in 1 bpm increment every time returns increase to 60% up to 9 bpm, 900 psi at 60 rpms, 13-14Kft-lbs. PBU V-205 downhole gauge showed an increase in pressure from 1700 psi to as high as 2250 psi once losses were observed. Projected to 7007' center to center of V-205L1 is 28', however we are within the ellipse to ellipse with a CF of 0.34. Wash down to 7007' at 375 gpm (80% returns), 900 psi, 80 rpms, 11-12Kft-lbs. At 7007' with 5K WOB string instantly torqued up to 21Kft-lbs. Pick up off bottom, no over pull. Max gas 542u. Increase flow to 425gpm with 92% returns. Circulate and reciprocate hole while discussing options with town Monitor well. Took 8 minutes to go static. Shut in MPD chokes, no pressure build. BROOH from 7007' to 5167' at 425 gpm, 1025 psi, 70-87% returns. 60-90 rpms (limited due to extreme pipe wobble on surface), 12Kft-lbs ECD 10.1 ppg with 9.35 ppg mud. Max gas 42u. P/U 180K, S/O 78K, ROT 118K. Observe wellbore breathing with flow out on connections continually slowing, and flow out while pumping gradually increasing. Start holding 75 psi on chokes to obtain better flow out after connections. Circulate bottoms up at 425 gpm, 970 psi, 96% returns, 85 rpms, 12Kft-lbs, reciprocating pipe. Monitor well, flow steadily decreased, no flow in 7 minutes. Shut MPD chokes and monitor for 5 minutes Pull MPD bearing, set trip nipple. 2 faults have been crossed so far this lateral: 6235', 6396'. 6 concretions have been drilled so far for a total footage of 22’ (1.2%) of the lateral. Drilled 872' in OBa-1 110' in OBa2 88' in OBa3, 757' out of zone. Projected distance to WP#11 at 7007': 22.27', 22.04' Low, 3.22' Right Daily Disposal to G&I = 456 bbls, total = 7436 bbls. Daily H2O from Lake 2 = 780 bbls total = 7180 bbls. Daily Metal: 0 lb. Total Metal 0 lb. Daily loss: 852 bbls Total production lost: 852 bbls. Total Surface Loss: 194 bbls. 3/10/2022 POOH on elevators from 5160' to 404'. See 20K overpull at 5160'. Kelly up and CBU rotating 30 rpm. No furthur issues pulling to 404'. PUW 43K, SOW 42K. Calc hole fill = 39 bbls, Act = 65 bbls, lost 26 bbls. Work BHA, racking back 4 stds HWDP/Jars. L/D flex collars and 2 float subs, Download MWD Data, L/D remaing BHA. Bit graded 2-3-BT-T-X-I-JD-HP. Clean and clear rig floor of BHA components. R/U to run 3 1/2" EUE cement string. R/U Weatherford Power Tongs, R/U 3 1/2" Handling equipment. RIH Picking up 3 1/2" EUE Tbg cement string to 1,026' MD. Tq to 3,200 ft/lbs. XO to 5" Drill pipe. PUW 44k, SOW 46K. Lost 12.9 bbls. R/D Tbg handling equipment and R/U 5" DP handling equipment. Static loss rate 20 bph. TIH with Cement String on 5" DP from 1,026' to casing shoe ~5150' P/U 133K, S/O 94K. Loss 21.6 bbls. Circulate bottoms up at 205 gpm, 180 psi, Max gas 27U P/U 134K, S/O 94K. Sim Ops: Service rig: grease and inspect crown sheaves, inspect iron roughneck, grease and inspect top drive, blocks. Dynamic loss rate 15 bph. Wash down cement stinger on 5" drill pipe from 5,150' to 7,000' at 105 gpm, 120 psi, max gas 23u. P/U 165K, S/O 93K. Lost 39 bbls. Circulate bottoms up while reciprocating pipe at 231 gpm, 260 psi, max gas 40u, P/U 168K, S/O 96K. Loss rate 17 bph. Cementers spot in and rig up. Blow down top drive. M/U 1502 head pin, swing, valve and tee to cement line. Pump cement as per detail: HES pump 5 bbls H2O at 3.7 bpm 300 psi. PT lines 1000/4000 psi - good. 40 bbls 10ppg tuned spacer at 3.5 bpm 225 psi. 45 bbls 15.8 ppg type I/II cementer at 3.5 bpm 400 psi. 10 bbls 10 ppg tuned spacer at 4 bpm, 200 psi. 5 bbls H2O 4 bpm 150 psi Swap to rig pumps. Displace with 53 bbls of mud at 6.5 bpm, 205 psi. With 2 bbls cement in open hole, shut annular. Squeeze 22 bbls of cement. Bring pumps on at 0.5 bpm, no pressure. Stage up to 3 bpm 81 psi, 4 bpm initial 288 psi, final 500 psi. Shut down and check pressures, holding 185 psi on drill pipe and annular. Bleed off pressures. Open annular. Continue displacing remaining 23 bbls cement at 2 bpm165 psi, leaving 2 bbls in tubing. Lost 15 bbls during cement job. CIP at 00:30. Calculated top of cement with no excess 6664'. Rig down cement lines and head pin. B/D cement line. POOH from 7000' to 6300' (5 stands above calculated cement top) at 20 fpm. P/U 168K, S/O 80K, Establish circulation at 3 bpm for 10 bbls. Break out of TD. Drop drill pipe wiper ball. Circulate surface to surface at 5 bpm, 220 psi. Lost 10 bbls during circulation. P/U 163K, S/O 93K. Monitor well, static. POOH from 6300' to 3905'. Pull first 3 stands, no indication of swabbing, pump dry job. P/U 112K S/O 85K. Calc displacement 22.4 bbls, Actu 24 bbls. Daily Disposal to G&I = 57 bbls, total = 7493 bbls. Daily H2O from Lake 2 = 390 bbls total = 7570 bbls. Daily Metal: 5 lb. Total Metal 5 lb. Daily loss: 441 bbls Total production lost: 1293 bbls. Total Surface Loss: 194 bbls. 3/11/2022 U 44K, S/O 46K RIH on elevators with 5" drill pipe from 404' to 5170'. Fill pipe at 2,620' and break in Geo-Pilot. BD top drive. P/U 155K, S/O 88K. Calculated displacement observed. Circulate bottoms up at 525 gpm, 1400 psi. Pull trip nipple, install MPD bearing. Wash and ream down from 5170' to 5360' at 450 gpm, 1140 psi, 60 rpms, 11Kft-lbs Sidetrack wellbore from 5360' to 5424'. Trough from 5360' to 5390' at 150 fph, 1 pass. Time drill from 5360' to 5400' at 50 fph with 100% deflection at 160R, reduce deflection to 50% from 5400' to 5410'. At 5406' ABI's show 1.9° inclination difference with 16" separation. at 5410' set Geo-pilot to inclination cruise at 75.69° with 20% right to 5424'. Ream through sidetrack point x 3. Shut down pumps and rotary and slack off through sidetrack point without issue, confirm in new hole with ABI's. Cont. drilling 8-1/2" hole from 5424' to 5808' (384' total, AROP 77fph) at 500 gpm, 1426 psi, WOB 10K, 100 rpms, 12Kft-lbs. Max gas 508u ECD 10.28 ppg with 9.4 ppg mud. P/U 177K, S/O 81K, ROT 115K. Backream half stands. Adjust rotary to maximize rpm's and minimize pipe wobble. Cont. drilling 8-1/2" hole from 5808' to 6525' (717' total, AROP 120fph) at 500 gpm, 1515 psi, WOB 10-12K, 100 rpms, 14-15Kft-lbs. Max gas 928u, ECD 10.4 ppg with 9.35 ppg mud. P/U 181K, S/O 78K, ROT 112K. Backream half stands. MPD chokes open. Entered OBa-1 at 5714'. Faulted from OBa-1 to OBa clay at 6184' with 20' DTSW throw. Entered OBa-3 at 6247'. Faulted from OBa-3 to OBa clay at 6304' with 5' DTSW throw. Entered OBa-3 at 6310' 2 faults have been crossed so far this lateral: 6184', 6304'. 4 concretions have been drilled so far for a total footage of 7’ (0.6%) of the lateral. One side track PB1 from 5360'-7007'. Drilled 470' in OBa-1, 137' in OBa-3 and 603' out of zone. Distance to WP12: 25.32', 6.51' high, 24.47' Right Daily Disposal to G&I = 115 bbls, total = 7608 bbls. Daily H2O from Lake 2 = 240 bbls total = 7810 bbls. Daily Metal: 4 lb. Total Metal 9 lb. Daily loss: 29 bbls Total production lost: 1322 bbls. Total Surface Loss: 194 bbls. 3/12/2022 Cont. drilling 8-1/2" hole from 6525' to 7396' (871' total, AROP 145fph) at 500gpm, 1725psi, WOB 10-12K, 100rpms, 15-16Kft-lbs. Max gas 748u, ECD 10.6 ppg, 9.4 ppg mud. P/U 186K, S/O 73K, ROT 109K. Backream half stands. At 7200' close one choke 80psi dynamic to mitigate gas flooding shakers. Cont. drilling 8-1/2" hole from 7396' to 8129' (733' total, AROP 122fph) at 500gpm, 1840psi, WOB 9-11K, 100rpms, 17Kft-lbs. Max gas 630u, ECD 11.16 ppg, 9.45 ppg mud. P/U 190K, S/O 60K, ROT 110K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Cont. drilling 8-1/2" hole from 8129' to 8861' (732' total, AROP 122fph) at 500gpm, 1940psi, WOB 9-11K, 100rpms, 19Kft-lbs. Max gas 936u, ECD 11.26 ppg, 9.35 ppg mud. P/U 200K, S/O N/A (lost S/O at 8,351'), ROT 110K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Cont. drilling 8-1/2" hole from 8861' to 9485' (624' total, AROP 124fph) at 500gpm, 2010psi, WOB 9-12K, 100rpms, 19-20Kft-lbs. Max gas 784u, ECD 11.28 ppg, 9.4 ppg mud. P/U 210K, S/O N/A, ROT 106K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. 2 faults have been crossed so far this lateral: 6184', 6304'. 12 concretions have been drilled so far for a total footage of 35’ (0.8%) of the lateral. One side track: PB1 from 5360'-7007'. Drilled 2099' in OBa-1, 625' in OBa-2, 858' in OBa-3 and 603' out of zone. Distance to WP12: 10.91', 10.8' high, 1.51' Right Daily Disposal to G&I = 855 bbls, total = 8463 bbls. Daily H2O from Lake 2 = 660 bbls total = 8470 bbls. Daily Metal: 4 lb. Total Metal 13 lb. Daily loss: 0 bbls total loss on mainbore 0 bbls. Total lost in PB1: 1322 bbls. Total Surface Loss: 194 bbls. 3/13/2022 Cont. drilling 8-1/2" hole from 9485' to 10238' (753' total, AROP 126fph) at 500gpm, 2040psi, WOB 6-10K, 100rpms, 19-20Kft-lbs. Max gas 1105u, ECD 11.2 ppg, 9.4 ppg mud. P/U 208K, S/O N/A, ROT 106K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Cont. drilling 8-1/2" hole from 10238' to 10295' (57' total, AROP 114fph) at 450gpm, 1765psi, WOB 6-10K, 100rpms, 21Kft-lbs. Max gas 499u, ECD 11.2 ppg, 9.4 ppg mud. P/U 212K, S/O N/A, ROT 105K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Consult with town and work on new directional plan due to survey not passing QC due to magnetic interference. Circulate hole at 450 gpm, 1600 psi, 60 rpms, 17Kft-lbs reciprocating pipe, max gas 600U. Cont. drilling 8-1/2" hole from 10295' to 10448' (153' total, AROP 77fph) at 450gpm, 1730psi, WOB 8-10K, 100rpms, 20Kft-lbs. Max gas 230u, ECD 10.97 ppg, 9.3 ppg mud. P/U 197K, S/O 48K ROT 109K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Exit Oa-1 top at 10,334' for anti- collision of V-122, and to move away from V-205 suspect causing magnetic interference. Cont. drilling 8-1/2" hole from 10448' to 10523' (75' total, AROP 50fph) at 450gpm, 1730psi, WOB 8-10K, 100rpms, 21Kft-lbs. Max gas 230u, ECD 10.97 ppg, 9.4 ppg mud. P/U 197K, S/O 48K, ROT 109K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Good survey obtained at 10523' (bit depth). Re-work directional plan due to close approaches. Circulate hole at 450 gpm, 1680psi, 30 rpms, 15Kft-lbs. Max gas 47u, ECD 10.9 ppg with 9.3 ppg mud. P/U 218K, S/O N/A, ROT 108K. Cont. drilling 8-1/2" hole from 10523' to 10672' (149' total, AROP 50fph) at 450gpm, 1825psi, WOB 7-10K, 100rpms, 18-20Kft-lbs. Max gas 75u, ECD 11.01 ppg, 9.4 ppg mud. P/U 202K, S/O 46K, ROT 109K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Continue getting a mix of good surveys and bad surveys with magnetic interference. Cont. drilling 8-1/2" hole from 10672' to 10802' (130' total, AROP 33fph) at 450gpm, 1825psi, WOB 7-10K, 100rpms, 18-20Kft- lbs. Max gas 55u, ECD 11.1 ppg, 9.4 ppg mud. P/U 202K, S/O 46K, ROT 109K. Backream full stands. MPD holding100 dynamic, 150 static to control gas flooding shakers. Continue getting a mix of good/bad surveys. Survey at 10,728' only showed a 0.66° dog leg, which is not sufficient to make the turn to miss the ellipse of V- 122. Consult options with town. Circulate bottoms up. Rack back stand. Pump tandem sweeps and continue circulating hole 450 gpm, 1835 psi, 80 rpms, 15Kft-lbs, ECD 11.0 ppg. Max gas 41u. P/U 200K, S/O 55K, ROT 109K. 2 faults have been crossed so far this lateral: 6184', 6304'. 15 concretions have been drilled so far for a total footage of 42’ (0.7%) of the lateral. One side track: PB1 from 5360'-7007'. Drilled 3068' in OBa-1, 625' in OBa-2, 858' in OBa-3 and 1071' out of zone. Distance to WP12 (projected to 10,802'): 27.44', 3.15' high, 27.26' Right Daily Disposal to G&I = 803 bbls, total = 9266 bbls. Daily H2O from Lake 2 = 1005 bbls total = 9475 bbls. Daily Metal: 2 lb. Total Metal 15 lb. Daily loss: 0 bbls total loss on mainbore 0 bbls. Total lost in PB1: 1322 bbls. Total Surface Loss: 194 bbls. 3/14/2022 Cont. circulating at 450 gpm, 1835 psi, 80 rpms, 15K-ftlbs, ECD 11.0 ppg. Reciprocating pipe. While discussing options with town regarding close approach of V- 122. BROOH from 10,767' to 8850' at 400 gpm, 1325 psi, 60 rpms, 14-15Kft-lbs. Max gas 28u, P/U 197K, S/O 78K, ROT 116K. Cont. BROOH from 8850' to 8600' at 400 gpm, 1300 psi, 60 rpms, 15Kft-lbs. max gas 32u. P/U 195K, S/O 82K, ROT 118K. Sidetrack wellbore from 8600' to 8669' at 150fph with 100% deflection at 170R, observed 3°/100 inclination drop. Roll toolface to 150L at 8651', 120L at 8666'. Ream through sidetrack and pass through with no pumps or rotary. Cont drilling 8-1/2" hole from 8669' to 9178' (total 509', AROP 113fph), 450 gpm, 1620 psi, WOB 8K, 110 rpms, 16Kft-lbs. max gas 840u. ECD 11.03 with 9.3 ppg mud. P/U 190K, S/O 54K, ROT 111K. Back ream full stands. Cont drilling 8-1/2" hole from 9178' to 9750' (total 572', AROP 95fph), 450 gpm, 1620 psi, WOB 8-12K, 110 rpms, 19Kft-lbs. max gas 655u. ECD 10.8 with 9.4 ppg mud. P/U 208K, ROT 112K. Lost slackoff wt at 9622' Back ream full stands. Cont drilling 8-1/2" hole from 9750' to 10,445' (total 695', AROP 116fph), 450 gpm, 1645 psi, WOB 8-12K, 100 rpms, 21Kft-lbs. max gas 716u. ECD 10.8 with 9.4 ppg mud. P/U 209K, ROT 109K. Back ream full stands. Start holding 100 psi with MPD at 10,123' to minimized gas flooding shakers. 2 faults have been crossed so far this lateral: 6184', 6304'. 14 concretions have been drilled so far for a total footage of 47’ (0.9%) of the lateral. Two side track: PB1 from 5360'-7007' PB2 8600'-10802'. Drilled 2987' in OBa-1, 621' in OBa-21,011' in OBa-3 and 603' out of zone. Distance to WP13: 14.33', 4.27' high, 13.68' Left Daily Disposal to G&I = 342 bbls, total = 9608 bbls. Daily H2O from Lake 2 = 510 bbls total = 9985 bbls. Daily Metal: 3 lb. Total Metal 18 lb. Daily loss: 0 bbls total loss on mainbore 0 bbls. Total lost in PB1: 1322 bbls. Total Surface Loss: 194 bbls. 3/15/2022 Cont drilling 8-1/2" hole from 10,445' to 11,145' (total 700', AROP 117fph), 475 gpm, 1980 psi, WOB 8-12K, 100 rpms, 21Kft-lbs, max gas 494u. ECD 11.3 with 9.4 ppg mud. P/U 222K, S/O N/A ROT 109K. Back ream full stands. Hold 100 psi with MPD minimized gas flooding shakers. Cont drilling 8-1/2" hole from 11,145' to TD at 11,832' (total 687', AROP 115fph), 475 gpm, 2050 psi, WOB 10-12K, 100 rpms, 24.5Kft-lbs. max gas 542u. ECD 11.5 with 9.4 ppg mud. P/U 230K, ROT 105K. Back ream full stands. Hold 100 psi with MPD to minimized gas flooding shakers. Obtain final survey Rack back stand. Pump tandem low vis/wt sweep and high vis/sweep (10% increase, on time) and circulated hole clean 4xBU. Rack back stand after sweeps are out and every bottoms up after. 450 gpm, 1825 psi, 50 rpms, 19Kft-lbs. max gas 310u, ECD 11.12 ppg with 9.4 ppg mud. MPD chokes open. Wash / ream to 11,832'. Pump SAPP train: (3) 40bbls SAPP pill followed by 20bbls, and displace to 9.3ppg Quickdril. At 330gpm, 1280psi, 80rpms, 19Kft-lbs. Max gas 30u. With good Quickdril all the way around observe TQ fall to 14-15Kft- lbs, ECD's fall from 10.92 ppg to 10.3 ppg. P/U 225K, S/O N/A, ROT 108K. Obtain passing PST test. Monitor well, static. Shut in MPD chokes for 5 min no pressure build. BROOH from 11,624' to 10,081' at 500 gpm, 1400 psi, 120 rpm, 13-14Kft-lbs, ECD 10.29 ppg with 9.3 ppg Quickdril. P/U 173K, S/O 66K, ROT 106K. Max gas 28u. Pulling speed 15-25 fpm as hole dictates. 2 faults have been crossed so far this lateral: 6184', 6304'. 17 concretions were drilled in the motherbore for a total footage of 56’ (0.8%) of the lateral. Two side track: PB1 from 5360'-7007' PB2 8600'-10802'. Drilled 4380' in OBa-1 621' in OBa-2 1,011' in OBa-3 and 640' out of zone. Distance to WP13 projected to TD: 8.11', 8.1' Low, 0.25' Left Daily Disposal to G&I = 974bbls, total = 10,582 bbls. Daily H2O from Lake 2 = 700 bbls total = 10,685 bbls. Daily Metal: 2 lb. Total Metal 20 lb. Daily loss: 0 bbls total loss on mainbore 0 bbls. Total lost in PB1: 1322 bbls. Total Surface Loss: 194 bbls. 3/16/2022 BROOH F/ 10,081' to 6,805' MD 500 gpm/ mpd 465 1,270 psi 120 rpm Trq 8-9k ECD 10.2, P/U 148k SLK 88k ROT 110k Max Gas 28u. Pull speed 25-35 ft/min, as hole dictates. At 8,600' MD trip in no pump/ ROT to 8,660' MD shot survey to verify in mother bore. MPD 100% open. Lost 47 bbls. Cont BROOH F/ 6,805' to 5,173' MD 500 gpm/ mpd 465 1,170 psi 120 rpm Trq 8-9k ECD 10.1, P/U 150k SLK 100k ROT 115k Max Gas 28u. Pull speed 25-35 ft/min, as hole dictates. At 5,615' MD observed erratic trq & slight over pull. At 5,360' MD trip in no pump/ ROT to 5,427' MD shot survey to verify in mother bore. Pull on elevators F/ 5,278' to 5,160' MD. At 5,160' MD pump 40 bbl 9.35 ppg 120 Vis sweep, on time W/ 10% increase. Perform passing PST. 500 gpm/ mpd 498 1,220 psi ECD 10.02 Max Gas 28u. P/U 142 SLK 103k ROT 115k. Monitor well 10 min, static, Shut in MPD 10 min, no press increase. PJSM Drain stack. Blow down TD. Pull RCD bearing and remove from stand as per Beyond rep onsite. Install trip nipple and tighten grey clamp. Inflate air boot and check for leaks, good. L/D RCD bearing. PJSM Hang blocks. Cut 12 wraps (75') drilling line. (ACTM 37,590) , Remove deadman & install dog knot on new line. Spool on new line. Trq deadman 85 ft/lb. Unhang blocks & tie back line. 91' left on spool. Static loss rate ~3.6 bph. PJSM Grease Crown, Perform monthly EAM wobble on clocks & crown sheaves. Grease & inspect TD. Check carriage for cracks, good. Service iron roughneck. C/O hydraulic elevators to manuals due to broken retaining bolts for the inserts. PJSM POOH L/D 5" D.P. F/ 5,160' to 5,095' MD. verify no swabbing. Pump 20 bbl Corrosion inhibited dry job. Blow down TD. Cont POOH L/D 5" D.P. F/ 5,095' to 3,093' MD. Cull pipe as per CAT 5 and hard band inspection. P/U 120k SLK 80k. Lost 5.2 bbls. Cont POOH L/D 5" D.P. F/ 3,093' to 705' MD. Cull pipe as per CAT 5 and hard band inspection. P/U 62k SLK 60k. Lost 7.4 bbls. RIH stands F/ the derrick F/ 705' to 2,105' MD. Lost 6.4 bbls. POOH L/D 5" D.P. F/ 2,105' to 404' MD. Cull pipe as per CAT 5 and hard band inspection. P/U 62k SLK 60k. Lost 8 bbls. PJSM L/D BHA L/D 6 ea 5" HWDP, 6.5" Hydra Jar, 3 ea NM FC, 2 ea FS & 1 ea 6.75 Integral Blade. Hook up and read MWD tools. 2 faults have been crossed so far this lateral: 6184', 6304'. 17 concretions were drilled in the motherbore for a total footage of 56’ (0.8%) of the lateral. Two sidetrack: PB1 from 5360'-7007' PB2 8600'-10802'. Drilled 4380' in OBa-1 621' in OBa-2 1,011' in OBa-3 and 640' out of zone. Daily Disposal to G&I = 1,502 bbls, total = 12,084 bbls. Daily H2O from Lake 2 = 290 bbls total = 10,975 bbls. Daily Metal: 2 lb. Total Metal 22 lb. Daily loss: 95 bbls total loss on mainbore 95 bbls. Total lost in PB1: 1322 bbls. Total Surface Loss: 194 bbls. 3/17/2022 Cont L/D BHA TM HOC, DM, PWD, ILS, ADR, GeoPilot, NRP & Bit. Bit grade 2-2-CT-A-X-I-WT-TD. Clear rig floor of BHA components. PJSM P/U R/U Weatherford 4.5" handling Equip and power tongs. Prep safety jnt on short side. TIW & 4.5" NC50 X 4.5" EZgo HT X/O on rig floor. Static loss rate 5 bph. PJSM P/U M/U 4.5" Shoe & slick jnt. Cont RIH W/ 4.5" EZGO HT 12.75# L-80 DELTA EXTREME W/ 5 GAGE (100-110 MIC RANGE3)1x solid Cent. & 4.5" 11.6# Welltec Mech Open Hole PKR EZGO HT BxP as per tally to 3,056' MD Trq EZGo HT average 6k. Run speed 60-70 ft/min. P/U 76k SLK 65k. PJSM Cont RIH W/ 4.5" EZGO HT 12.75# L-80 DELTA EXTREME W/ 5 GAGE (100-110 MIC RANGE3)1x solid Cent. & 4.5" 11.6# Welltec Mech Open Hole PKR EZGO HT as per tally F/ 3,056' to 6,804' MD Trq EZGo HT average 6k. Run speed 60-70 ft/min. P/U 109k SLK 87k. Lost 29 bbls. At PB 1 5,360' MD 8 FPH, no issue C/O to 5" elevators. P/U M/U 7" X 9.625" SLZXP Liner Top Packer with DG slips (11.28' sleeve) Lost 29 bbls for trip. Convey 4.5" Screen Liner W/ 5" 19.5# S-135 NC50 D.P. F/ 6,804' to 8,194' MD. Circ through SLZXP 1.25 bpm 50 psi, 3.125 bpm 200 psi. Run speed 40-60 ft min to 8,198' MD tag up 25k, work though & cont at 20- 30 ft/min as hole dictates. P/U 140k SLK 78k. Cont Convey 4.5" Screen Liner W/ 5" 19.5# S-135 NC50 D.P. F/ 8,194' to 11,832' MD tag TD W/ 10k. L/D jnt from stand 179. Set shoe depth at 11,800' MD. Run speed 20-30 ft/min as hole dictates. P/U 180k SLK 78k. Encountered tight spots @ 8,198', 10,198', 10,387', 10,521', 10,557', 10,770', 10,848' & 11,495' MD. Break Circ at 3 bpm 280 psi for 20 bbls ensure no issue Circ through SLZXP. PJSM Drop 1" OD Phenolic ball. Pump down at 3 bpm 265 psi and slowed to 1 bpm 90 psi at 1,000 stks. Ball on seat at 1,054 stks, 376 stks early. Increase Press to 2,200 psi setting packer, hold for 2 min. SLK down F/ 168k to 99k, P/U 183k Press up to 2,400 psi SLK 94k P/U 189k SLK 90k. Press up to 2,900 psi 1 min, released from HRD, increase to 3,500 psi neutralizer shifted at 3,340 psi. Line up on test pump and increase Press to 5,000 psi to shear ITTS tool open. Setting TOL at 5,010' MD. PJSM P/U to verify free W/ new P/U 141k SLK 107k. Blow down TD. Flood kill line, close UPR and flood choke manifold. Press up and test SLZXP 1,500 psi for 10 min on chart, good. Pumped 1.8 bbls, bled back 1.7 bbls. R/D test Equip. PJSM Circ at 2 bpm 80 psi F/ 5,021' to 5,000' MD. L/D single jnt & 9.59' pup jnt. Displace 9.3 ppg QuickDril W/ 365 bbls 9.3 ppg Corrosion Inhibited Brine at 8 bpm 615 psi. Max Gas 89u, no losses. Monitor well 10 min, static. PJSM Pump 15 bbls 10.1 ppg dry job. Blow down TD. POOH L/D 5" D.P. F/ 5,000' to 1,100' MD. Cull 5" D.P. for CAT 5 inspection. P/U 58k SLK 59k. Lost 11.4 bbls. Daily Disposal to G&I = 57 bbls, total = 12,141 bbls. Daily H2O from Lake 2 = 0 bbls total = 10,975 bbls. Daily Metal: 0 lb. Total Metal 22 lb. Daily loss: 200 bbls total loss on mainbore 200 bbls. Total lost in PB1: 1322 bbls. Total Surface Loss: 194 bbls. Activity Date Ops Summary 3/18/2022 Continue to L/D 5" DP from 1100, to 620' MD, culling out DP as per cat 5 inspection Tally. PUW 48K, SOW 49K.,RIH with remaing DP in Derrick from 620' to 1692'. PUW 64K SOW 64K,Continue to L/D 5" DP from 1692, to Surface, culling out DP as per cat 5 inspection Tally. L/D SLZXP running tool as per Baker Rep. Calc 18.9 bbls, Act 29.4 bbls, Loss 10.5 bbls.,De-Energize Koomy, Open doors and Change out UPR from 2.875" x 5" VBR's to 7" Fixed Ram. Tighten doors and re- energize Koomy,Top hole off. 3 bph static loss rate. P/U test jnt & wear ring running tool. BOLDS & remove wear ring. Set test plug & M/U headpin to test jnt. R/U test Equip. Fill & flood lines. Perform shell test 3,000 psi, good.,PJSM Test UPR 7" solid body to 250/ 3,000 psi 5 min on chart.,PJSM Pull test plug. R/D test Equip & L/D test tools. Blow down kill, choke and manifold.,PJSM Clean & clear rig floor. Stage Weatherford 7" handling Equip and Trq turn. Prep pipe shed for running 7" tie back.,PJSM C/O 5" elevators to 7" 200T side doors. R/U Weatherford power tongs and Trq turn Equip.,PJSM RIH W/ 7" 29# L-80 JFE to 5,018' MD. Observed 5k seal drag and set down 10k on NoGo to verify TOL at 5,010' MD. Trq turn JFE to 17,320 ft/lb. Run speed 60 FPM. P/U 156k SLK 123k. Lost 38 bbls.,Verify 5 jnts left. L/D Jnts 136, 135 & 134. Calculate space out. P/U Pups 9.82', 7.82', 5.82k & Jnt 134. P/U M/U 7" Mandrel and landing joint. Land mandrel W/ 0.84" off NoGo. Vault rep verify mandrel landed on load shoulder. Weight on Hanger 88k. R/U reverse Circ Equip. R/U LRS to 7" X 9 5/8" Annulus. Flood kill line, close annular. Press up 7" X 9 5/8" to 500 psi, seals good. Bleed down to 250 psi and strip up seeing,press dump exposing seals.,PJSM LRS test lines 300/ 3000 psi, good. LRS reverse circ 53 bbls Diesel 9 5/8" X 7" annulus. 1 bpm 180 psi, 2 bpm icp 280 psi FCP 530 psi.,PJSM Strip down and land 7" mandrel W/ 88k. LRS bleed off 215 psi. Break out landing jnt and L/D. Blow down TD. Pull & L/D mouse hole. C/O elevators to 5". P/U jnt and pack off. Set 7" pack off as per Vault rep onsite. RILDS. PT Void 500/ 5000 psi 10 min, good.,PJSM R/U LRS to 7" X 9.625" annulus. Test 1,500 psi for 30 min on chart, good. Pump 1.15 bbls bled 1.1 bbls. R/D LRS & tetst Equip. SIMOPS C/O Elevators to 4.5". Prep pipe shed W/ 4.5" jewelry.,PJSM Bring X/O for TIW. Dump test Trq turn. P/U M/U WLEG Shoe Baker Loc all components to to Baker S-3 Production Packer. Cont RIH W/ 4.5" 12.6# L-80 Vam as per tally to 563' MD. Trq turn Vam to 4,400 ft/lb. P/U 37k SLK 38k. Lost 3.6 bbls.,Daily Disposal to G&I = 694 bbls, total = 12,835 bbls. Daily H2O from Lake 2 = 0 bbls total = 10,975 bbls. Daily Metal: 0 lb. Total Metal 22 lb. Daily loss: 74 bbls Production total lost: 74 bbls. 3/19/2022 Cont RIH 4.5" 12.6# L-80 Vam Gas Lift completion F// 563' to 4,952' MD. P/U M/U Landing Hanger per Vault Rep onsite. Speed 80 ft/min. Trq Turn 4,440 ft/lb. P/U 82k SLK 72k. Lost 7.6 bbls.,PJSM Drain stack. Land hanger as per Vault rep onsite. Verify landed ROLDS. WT in hanger 38k.,PJSM L/D landing jnt. C/O elevators to 5". P/U 20' 5" pup W/ 3.5" TC-II X/O. M/U to hanger. R/U 1502 components and HP hoses to IA and tubing. Circ 2 bpm 104 psi to ensure flow path. Remove head pin and drop ball & rod. Install TIW & side entry sub to 20' pup to tubing.,PJSM Flood lines and purge air. Line up on tubing and Press up to 2,000 psi hold 5 min shearing Baker S-3 screws, Cont to Press up to 4,000 psi setting S-3 Packer. MIT 4.5" 3,700 psi for 30 min on chart, good. Bleed down tubing to 2,000 psi and shut in. MITIA 3,700 psi for 30 min on chart, good. Bleed down tubing and observe GLM valve shear about 2,500 psi. Reverse Circ 10 bbls 2 bpm 320 psi through GLM, good.,Blow test Equip and R/D. Vault Rep set BPV.,PJSM M/U and Johnny Whack stack. Flush all surface lines and manifold. Blow down all surface lines.,PJSM Deenergize Koomey. C/O UPRs F/ 7" solid body to 2.875" X 5.5" VBRs. Close door and tighten bolts. SIMOPS Remove split bushings. Open grey clamp and remove trip nipple.,PJSM R/D MPD hard lines, drip pan, choke & kill lines. Break bolts on DSA. P/U BOP remove lower bolts. Set back down and unbolt DSA. Move BOP to pedestal and secure. Remove DSA & set aside. SIMOPS: Clean Pits. Inspect MP 1 & 2 & perform monthly EAM's. Replace 6" Butterfly valve on charge pump #1.,PJSM Install Tree as per Vault Rep onsite. Test void 500/ 5,000 psi 10 min each, good. R/U test Equip. Test Tree 250/ 5000 psi 10 min each, good.,PJSM R/D testing Equip. Vault rep pull TWC. R/U U Tube manifold for reverse circulating FP taking returns to cutting box. Daily Disposal to G&I = 228 bbls, total = 13,063 bbls. Daily H2O from Lake 0 = 0 bbls total = 10,975 bbls. Daily Metal: 0 lb. Total Metal 22 lb. Daily loss: 7 bbls Production total lost: 81 bbls. 3/20/2022 PJSM LRS PT lines 300/ 3000 psi, good. LRS pump 66 bbls Diesel down IA 7" X 4.5" 1 bpm ICP 250 psi, 1.5 bpm FCP 500 psi. Shut in and R/D LRS. Open up U Tube manifold and allow Diesel to balance out. SIMOPS Cont cleaning pits and MP's. Check tires for rig move. Release rig at 02:30. PJSM U Tube pressure 250 psi dropping to 125 psi, shut in and R/D. Clean cellar. Cont cleaning pits. Finish re assemble MP's. C/O Bell Guide, dies and Saver Sub to 4" XT39. PT Halliburton valves and install to cement line manifold. R/D pits/ Mezz inner connects. Safe out stairs and walkways. Put heat on stampers. Remove companion flanges from wellhead. 3/1/2022Spud Date: Well Name: Field: County/State: PBW V-234 Prudhoe Bay West Hilcorp Energy Company Composite Report , Alaska 50-029-23707-00-00API #: TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 1 75 46 X Yes No X Yes No 20 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:Yes X No Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 1.17 3/6/2022 25 Spud Mud Type I/II 425 2.35 Type I/II 412 1.16 4.3 1,958.00 Crossover 9 5/8 47.0 L-80 Vam21xTX 28.18 1,958.00 1,929.82 1,977.42 1,974.59 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 16.59 1,974.59 16.38 1,993.80 1,977.42 ES Cementer 10 3/4 40.0 L-80 TXP Halliburton 2.83 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 5,054.78 Casing 9 5/8 40.0 L-80 TXP Tenaris 3,060.98 5,054.78 1,993.80 5,095.54 5,056.22 Baffle Adapter 10 3/4 40.0 L-80 TXP Halliburton 1.44 5,056.22 1.46 5,097.00 5,095.54 Casing 9 5/8 40.0 L-80 TXP Tenaris 39.32 Float Collar 10 3/4 40.0 L-80 BTC DHS 1 ea Jnt 1, 2 ea jnt 2, 1 every joint to jnt 25, 1 every other to jnt 49. 5 before and after ES Cementer, 1 on ES cementer pup joint. 1 every third to jnt 119 Casing 9 5/8 40.0 L-80 TXP Tenaris 82.06 5,179.06 5,097.00 www.wellez.net WellEz Information Management LLC ver_04818br 5.3 208.34Water 4.3 Ftg. Returned Ftg. Cut Jt. Ftg. Balance No. Jts. Delivered 159 No. Jts. Run 125 34 Length Measurements W/O Threads Ftg. Delivered Ftg. Run 26.90 RKB to CHF Type of Shoe:Bullnose Casing Crew:Weatherford 12 178 Water ES Cementer Closure OK 5.5208.34 57 Type I/II Type Type I/II 274 Tuned Spacer 444 2.88 Stage Collar @ 60 Bump press 100 140 5,180.825,190.00 CEMENTING REPORT Csg Wt. On Slips:40,000 Spud Mud 23:50 3/5/2022 1,974 1974.59 15.8 85 Bump press Returns to Surface Bump Plug? yes 4.5 9.5 3 124/124.5 372.3/358 50 Rig/HalliburtonFIRST STAGE10Tuned Spacer 67 15.8 620 9.6 2 1900 10 10.7 228 4.5 100 550 Bump Plug? Csg Wt. On Hook:253,000 Type Float Collar:Conventional No. Hrs to Run:18 25.78 9 5/8 47.0 L-80 Vam21 Vam 37.279 5/8 47.0 L-80 Vam 21 Vam 11.49 BTC DHS 1.76 5,180.82 5,179.06 1,892.55 1,929.82 37.27 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.PBW V-234 Date Run 4-Mar-22 CASING RECORD County State Alaska Supv.S. Barber/ C. Montague 5,095.54 Floats Held 339.27 548 190 358 Spud Mud/Spacer Rotate Csg Recip Csg Ft. Min. PPG9.6 Shoe @ 5180.82 FC @ Top of Liner #N/A SECOND STAGERig 11:13 Cement to Surface 277.67 296.4 6.7 Casing (Or Liner) Detail Shoe Casing Cut Joint 10 3/4 40.0 L-80 Cement to Surface Returns to Surface !" #$"%% &' ( ' ! ' ) ' ' *' *+ ' '!"" #$$%&'( ,-' +,' ) *+ ,- -- ' #$$%&'( ' . * ,(' . (' & /' ,( ('+ /& $012 ( 3 -/& $0 -) ) + 3 + 4*1 *-*1 -(56 ' ! +(7. +(77 ( * * , - ' ' 0,-' -' ( 102!* 12! ,3 ( ( ( . ' ( ( '%'' '%'' 8&$'' %&9 8&' :8%& 8/%''* 0'( '%8' $';/&< '% 9 / &;/:</%:8&. *+ 456 7 - 4)6 ( 8- 456 (-, ==! 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( * ( ( +( + , ( (!"" #$$%&'( -.( ,-( ) *+ ,- -- ( #$$%&'( ( . * - D 5 D D Benjamin Hand Digitally signed by Benjamin Hand Date: 2022.03.24 11:19:21 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2022.03.24 12:54:01 -08'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 04/05/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL : PBU V-234 (PTD: 222-004 API: 50-029-23707-00-00) FINAL LWD FORMATION EVALUATION LOGS (03/01/2022 to 03/15/2022) x EWR-M5, AGR, ABG, DGR, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey x Final Geosteering and EOW Report/Plots SFTP Transfer – Main Folders: PBU V-234 LWD Subfolders: PBU V-234 Geosteering Subfolders:g Please include current contact information if different from above. 222-004 T36443 T36444: PB1 T36445: PB2 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.04.05 13:19:59 -08'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC PBU V-234PB1 (PTD: 222-004 API: 50-029-23707-70-00) FINAL LWD FORMATION EVALUATION LOGS (03/01/2022 to 03/09/2022) x EWR-M5, AGR, ABG, DGR, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey PBU V-234PB1 LWD Subfolders: PBU V-234PB2 (PTD: 222-004 API: 50-029-23707-71-00) FINAL LWD FORMATION EVALUATION LOGS (03/01/2022 to 03/14/2022) x EWR-M5, AGR, ABG, DGR, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Survey PBU V-234PB2 LWD Subfolders: Please include current contact information if different from above. CAUTION: This email originated from outside the State of Alaska mail system. From:Shane Barber To:Regg, James B (OGC) Cc:Brooks, Phoebe L (OGC); Clint Montague; James Lott; Oliver Amend; Joseph Engel Subject:RE: [EXTERNAL] RE: Innovation BOP test form Date:Wednesday, March 9, 2022 10:04:01 AM Jim, Phoebe has previously sent emails in regards to this very thing and probably feels like it has fallen on deaf ears, for that I apologize. I believe it was a carry over and was accounting for a Non BOP component Demco to mud pumps which shouldn’t be involved in BOP test. I just spoke with pusher and we will pass this along to all supervisors on “Innovation” in which I have included in this email. Please see attached revised test form. Thank you. Shane G. Barber | Drilling Foreman Hilcorp Alaska, LLC Rig “Innovation” Office: 907-670-3094 Mobile: 907-841-5208 sbarber@hilcorp.com From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, March 9, 2022 9:49 AM To: Shane Barber <sbarber@hilcorp.com> Subject: [EXTERNAL] RE: Innovation BOP test form What is the BOP Misc component (Result 1, P)? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Shane Barber <sbarber@hilcorp.com> Sent: Tuesday, March 8, 2022 8:18 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Joseph Engel <jengel@hilcorp.com>; Nathan Sperry <Nathan.Sperry@hilcorp.com>; Clint Montague <cmontague@hilcorp.com>; James Lott <jlott@hilcorp.com> Subject: Innovation BOP test form PBU V-234 PTD 2220040 J. Regg; 3/9/2022 Do not click links or open attachments unless you recognize the sender and know the content is safe. All, Please see attached BOP test form. Innovation PBU V-234. Thank you. Shane G. Barber | Drilling Foreman Hilcorp Alaska, LLC Rig “Innovation” Office: 907-670-3094 Mobile: 907-841-5208 sbarber@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Contractor:Rig No.:Innovation DATE:3/7/22 Rig Rep.:Rig Phone:670-3070 Operator:Op. Phone:670-3094 Rep.:E-Mail Well Name:PTD #2220040 Sundry # Operation:Drilling:x Workover:Explor.: Test:Initial:x Weekly:Bi-Weekly: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:1530 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec.P Ball Type 2 P Standing Order Posted P Misc.NA Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13-5/8", 5K P Pit Level Indicators P P #1 Rams 1 2-7/8"x5-1/2"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2-7/8"x5-1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3-1/8, 5K P Inside Reel valves 0 NA HCR Valves 2 3-1/8, 5K P Kill Line Valves 2 3-1/8, 5K P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 1 P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1500 P Quantity Test Result 200 psi Attained (sec)21 P No. Valves 15 P Full Pressure Attained (sec)93 P Manual Chokes 1 P Blind Switch Covers:All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.):6 @ 2380 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures:0 Test Time:5.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/6, 04:18 Waived By Test Start Date/Time:3/7/2022 6:30 (date)(time)Witness Test Finish Date/Time:3/7/2022 11:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Test on 4.5" and 5" Pipe Size. Tested annular 3000 psi. Joel Sture Hilcorp Shane Barber PBU V-234 Test Pressure (psi): sbarber@hilcorp.com Form 10-424 (Revised 05/2021)2022-0307_BOP_Hilcorp_Innovation_PBU_V-234 −−−−−−−−JBR J. Regg; 3/9/2022 Date: 3/1/2022 Development: X Exploratory: Drlg Contractor: Rig No. Innovation AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.: 2220040 Rig Phone: Rig Email: MMISCEL L ANEOUS:DIVERTER SYSTEM: Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice: P Vent line Below Diverter? P AACCUMUL ATOR SYSTEM:Diverter Size: 13 5/8 in. Systems Pressure: 2950 psig P Hole Size: 12 1/4 in. Pressure After Closure: 1950 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time: 17 Seconds P Vent Line(s) Length: 215 ft. P Full Recharge Time:56 Seconds P Closest Ignition Source: 80 ft. P Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 199 ft. P Avg. Pressure: 2333 psig Accumulator Misc: NA Vent Line(s) Anchored: P MMUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: NA Trip Tank: P P Divert Valve(s) Full Opening: P Mud Pits: P P Valve(s) Auto & Simultaneous: Flow Monitor: P P Annular Closed Time: 9 sec P Mud System Misc: 0 NA Knife Valve Open Time: 7 sec P Diverter Misc: NA GGAS DETECTORS:Visual Alarm Methane: P P Hydrogen Sulfide: P P Gas Detectors Misc: 0 NA Total Test Time: 0.5 hrs Non-Compliance Items: 0 Remarks: Submit to: SSTATE OF AL ASK A AAL ASK A OIL AND GAS CONSERVATION COMMISSION DDi v er t er Sys t em s In s p ec t i o n Rep o r t GGENERAL INFORMATION WaivedHilcorp **Al l Di v er t er r ep o r t s ar e d u e t o t h e ag en c y w i t h i n 5 d ay s o f t es t i n g * sbarber@hilcorp.com TTEST DATA Joel Sture phoebe.brooks@alaska.gov Hilcorp Annular tested on joint of 5" DP. 0 Shane Barber 0 907-670-3094 TTEST DETAIL S jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov PBU V-234 Form 10-425 (Revised 05/2021)2022-0301_Diverter_Hilcorp_Innovation_PBU_V-234 9 9 9 9 9 9 9 9 -%5 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manger Hilcorp North Slope, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, PBU V-234 Hilcorp North Slope, LLC Permit to Drill Number: 222-004 Surface Location: 4798’ FSL, 1935’ FEL, SEC. 11, T11N, R11E, UM, AK Bottomhole Location: 2633’ FSL, 2270’ FWL, SEC. 01, T11N, R11E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced 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 January, 2022. 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3º/100' : 596.9' MD, 596.74'TVDStart Dir 4º/100' : 796.9' MD, 795.16'TVDEnd Dir : 1221.56' MD, 1196.56' TVDStart Dir 5º/100' : 3616.41' MD, 3332.34'TVDFault #1 (30' Throw)End Dir : 5569.77' MD, 4501.1' TVDStart Dir 4º/100' : 5669.77' MD, 4501.1'TVDEnd Dir : 6106.3' MD, 4498.95' TVDStart Dir 3.5º/100' : 6196.99' MD, 4498.07'TVDEnd Dir : 7406.71' MD, 4518.86' TVDStart Dir 3º/100' : 9487.06' MD, 4578.43'TVDStart Dir 2.5º/100' : 9673.21' MD, 4581.1'TVDEnd Dir : 9862.68' MD, 4580.33' TVDStart Dir 2.5º/100' : 10382.63' MD, 4576.1'TVDEnd Dir : 10921.38' MD, 4575.23' TVDTotal Depth : 12119.2' MD, 4581.1' TVDBPRFSV3SV1Ugnu 4UG3Ugnu MBOAOBaHilcorp North Slope, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: V-23449.60+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005970042.94590365.94 70° 19' 40.437 N 149° 16' 1.658 WSURVEY PROGRAMDate: 2021-12-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 1350.00 V-234 wp06 (V-234) 3_Gyro-MWD90+Sag1350.00 5670.00 V-234 wp06 (V-234) 3_MWD+IFR2+MS+Sag5670.00 12119.20 V-234 wp06 (V-234) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1778.10 1702.00 1873.64 BPRF2138.10 2062.00 2277.31 SV32902.10 2826.00 3133.98 SV12917.10 2841.00 3150.80 Ugnu 43292.10 3216.00 3571.29 UG34103.10 4027.00 4527.40 Ugnu MB4436.10 4360.00 5160.73 OA4501.10 4425.00 5569.77 OBaREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-234, True NorthVertical (TVD) Reference:V-234 As-staked RKB @ 76.10usftMeasured Depth Reference:V-234 As-staked RKB @ 76.10usftCalculation Method: Minimum CurvatureProject:Prudhoe BaySite:VWell:Plan: V-234Wellbore:V-234Design:V-234 wp06CASING DETAILSTVD TVDSS MD SizeName4501.10 4425.00 5670.00 9-5/8 9 5/8" x 12 1/4"4581.10 4505.00 12119.20 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 396.90 0.00 0.00 396.90 0.00 0.00 0.00 0.00 0.00 Start Dir 2º/100' : 396.9' MD, 396.9'TVD3 596.90 4.00 195.00 596.74 -6.74 -1.81 2.00 195.00 -5.47 Start Dir 3º/100' : 596.9' MD, 596.74'TVD4 796.90 10.00 195.00 795.16 -30.27 -8.11 3.00 0.00 -24.55 Start Dir 4º/100' : 796.9' MD, 795.16'TVD5 1221.56 26.90 201.15 1196.56 -156.40 -52.65 4.00 9.56 -135.446 3616.41 26.90 201.15 3332.34 -1166.80 -443.63 0.00 0.00 -1051.32 Start Dir 5º/100' : 3616.41' MD, 3332.34'TVD7 5569.77 90.00 94.00 4501.10 -1811.15 649.76 5.00 -105.39 -556.82 End Dir : 5569.77' MD, 4501.1' TVD8 5669.77 90.00 94.00 4501.10 -1818.12 749.51 0.00 0.00 -480.85 V-234 wp03 Heel Start Dir 4º/100' : 5669.77' MD, 4501.1'TVD9 6106.30 90.56 76.55 4498.95 -1782.29 1182.87 4.00 -88.14 -111.40 End Dir : 6106.3' MD, 4498.95' TVD10 6196.99 90.56 76.55 4498.07 -1761.20 1271.07 0.00 0.00 -27.99 Start Dir 3.5º/100' : 6196.99' MD, 4498.07'TVD11 6330.39 89.50 72.00 4498.00 -1725.05 1399.44 3.50 -103.10 96.65 V-234 wp01 CP112 7406.71 88.36 34.34 4518.86 -1091.59 2245.38 3.50 -92.04 1153.47 End Dir : 7406.71' MD, 4518.86' TVD13 9487.06 88.36 34.34 4578.43 625.49 3418.39 0.00 0.00 3118.44 Start Dir 3º/100' : 9487.06' MD, 4578.43'TVD14 9673.21 90.00 29.00 4581.10 783.84 3516.07 3.00 -72.96 3291.22 V-234 wp01 CP3 Start Dir 2.5º/100' : 9673.21' MD, 4581.1'TVD15 9862.68 90.47 24.29 4580.33 953.14 3601.01 2.50 -84.35 3460.29 End Dir : 9862.68' MD, 4580.33' TVD16 10382.63 90.47 24.29 4576.10 1427.06 3814.86 0.00 0.00 3914.34 V-234 wp01 CP4 Start Dir 2.5º/100' : 10382.63' MD, 4576.1'TVD17 10921.38 89.72 10.84 4575.23 1939.52 3977.05 2.50 -93.15 4349.85 End Dir : 10921.38' MD, 4575.23' TVD18 12119.20 89.72 10.84 4581.10 3115.96 4202.27 0.00 0.00 5231.47 V-234 wp01 Toe Total Depth : 12119.2' MD, 4581.1' TVD -1950 -1625 -1300 -975 -650 -325 0 325 650 975 1300 1625 1950 2275 2600 2925 3250 South(-)/North(+) (650 usft/in)-325 0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 West(-)/East(+) (650 usft/in) V-234 wp03 Heel V-234 wp01 Toe V-234 wp01 CP4 V-234 wp01 CP3 V-234 wp01 CP2 V-234 wp01 CP1 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 750 1250 1500 1750 2000 2250 2500 2750 3000 3250 3 7 5 0 4000425045004581 V-234 wp06 Start Dir 2º/100' : 396.9' MD, 396.9'TVD Start Dir 3º/100' : 596.9' MD, 596.74'TVD Start Dir 4º/100' : 796.9' MD, 795.16'TVDEnd Dir : 1221.56' MD, 1196.56' TVD Start Dir 5º/100' : 3616.41' MD, 3332.34'TVD Fault #1 (30' Throw) End Dir : 5569.77' MD, 4501.1' TVD Start Dir 4º/100' : 5669.77' MD, 4501.1'TVD End Dir : 6106.3' MD, 4498.95' TVD Start Dir 3.5º/100' : 6196.99' MD, 4498.07'TVD End Dir : 7406.71' MD, 4518.86' TVD Start Dir 3º/100' : 9487.06' MD, 4578.43'TVD End Dir : 9862.68' MD, 4580.33' TVD Start Dir 2.5º/100' : 10382.63' MD, 4576.1'TVD End Dir : 10921.38' MD, 4575.23' TVD Total Depth : 12119.2' MD, 4581.1' TVD CASING DETAILS TVD TVDSS MD Size Name 4501.10 4425.00 5670.00 9-5/8 9 5/8" x 12 1/4" 4581.10 4505.00 12119.20 4-1/2 4 1/2" x 8 1/2" Project: Prudhoe Bay Site: V Well: Plan: V-234 Wellbore: V-234 Plan: V-234 wp06 WELL DETAILS: Plan: V-234 49.60 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 5970042.94 590365.94 70° 19' 40.437 N 149° 16' 1.658 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: V-234, True North Vertical (TVD) Reference:V-234 As-staked RKB @ 76.10usft Measured Depth Reference:V-234 As-staked RKB @ 76.10usft Calculation Method:Minimum Curvature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lan: V-234 NAD 1927 (NADCON CONUS)Alaska Zone 0449.60+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005970042.94590365.9470° 19' 40.437 N149° 16' 1.658 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-234, True NorthVertical (TVD) Reference:V-234 As-staked RKB @ 76.10usftMeasured Depth Reference:V-234 As-staked RKB @ 76.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-12-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 1350.00 V-234 wp06 (V-234) 3_Gyro-MWD90+Sag1350.00 5670.00 V-234 wp06 (V-234) 3_MWD+IFR2+MS+Sag5670.00 12119.20 V-234 wp06 (V-234) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700Measured Depth (600 usft/in)V-201V-203V-205V-205L1V-205L2V-214V-02V-101V-104V-107V-108V-114V-202V-210V-211GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference26.50 To 12119.20Project: Prudhoe BaySite: VWell: Plan: V-234Wellbore: V-234Plan: V-234 wp06Ladder / S.F. 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eparation Factor5600 5950 6300 6650 7000 7350 7700 8050 8400 8750 9100 9450 9800 10150 10500 10850 11200 11550 11900 12250Measured Depth (700 usft/in)V-122V-122PB1V-205V-205L1V-205L2V-115V-115L1V-115L2No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: V-234 NAD 1927 (NADCON CONUS)Alaska Zone 0449.60+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005970042.94590365.9470° 19' 40.437 N149° 16' 1.658 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-234, True NorthVertical (TVD) Reference:V-234 As-staked RKB @ 76.10usftMeasured Depth Reference:V-234 As-staked RKB @ 76.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2021-12-15T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 1350.00 V-234 wp06 (V-234) 3_Gyro-MWD90+Sag1350.00 5670.00 V-234 wp06 (V-234) 3_MWD+IFR2+MS+Sag5670.00 12119.20 V-234 wp06 (V-234) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)5600 5950 6300 6650 7000 7350 7700 8050 8400 8750 9100 9450 9800 10150 10500 10850 11200 11550 11900 12250Measured Depth (700 usft/in)V-205L1V-205L1V-205L2V-205L2GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference26.50 To 12119.20Project: Prudhoe BaySite: VWell: Plan: V-234Wellbore: V-234Plan: V-234 wp06Ladder / S.F. 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