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Home My WebLink About220-062MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC L-21A MILNE PT UNIT L-21A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/10/2025 L-21A 50-029-22629-01-00 220-062-0 W SPT 7051 2200620 1763 2050 2052 2050 2053 22 333 331 330 4YRTST P Guy Cook 11/12/2024 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT L-21A Inspection Date: Tubing OA Packer Depth 250 2719 2665 2655IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC241111175653 BBL Pumped:2.8 BBL Returned:2.8 Friday, January 10, 2025 Page 1 of 1 999 9 9 9 9 9 9 9 999 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2025.01.10 16:18:50 -09'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/30/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-21A (PTD 220-062) IPROF 12/11/2021 Please include current contact information if different from above. Received By: 01/03/2022 37' (6HW By Abby Bell at 9:45 am, Jan 03, 2022 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22629-01-00Well Name/No. MILNE PT UNIT L-21ACompletion Status1WINJCompletion Date11/4/2020Permit to Drill2200620Operator Hilcorp Alaska, LLCMD14109TVD7398Current Status1WINJ2/9/2021UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, ABG, PCG, ADR, ALD, CTN MD & TVD, Cement EvaluationNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF11/5/202010173 14109 Electronic Data Set, Filename: MPU L-21A LWD Final.las34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final MD.cgm34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final TVD.cgm34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A_Definitive Survey Report.pdf34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A_Definitive Survey Report.txt34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A_GIS.txt34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A_Surveys.xlsx34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final MD.emf34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final TVD.emf34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final MD.pdf34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final TVD.pdf34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final MD.tif34193EDDigital DataDF11/5/2020 Electronic File: MPU L-21A LWD Final TVD.tif34193EDDigital DataDF11/5/2020 Electronic File: EMFView3_1.zip34193EDDigital DataDF11/5/2020 Electronic File: Readme.txt34193EDDigital Data0 0 2200620 MILNE PT UNIT L-21A LOG HEADERS34193LogLog Header ScansDF11/19/202014035 12930 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Main.las34290EDDigital DataDF11/19/202014042 13823 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Repeat.las34290EDDigital DataTuesday, February 9, 2021AOGCCPage 1 of 3MPU L-21A LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22629-01-00Well Name/No. MILNE PT UNIT L-21ACompletion Status1WINJCompletion Date11/4/2020Permit to Drill2200620Operator Hilcorp Alaska, LLCMD14109TVD7398Current Status1WINJ2/9/2021UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDDF11/19/202014035 12930 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Main.las34290EDDigital DataDF11/19/202014042 13823 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Repeat.las34290EDDigital DataDF11/19/2020 Electronic File: MPU_L-21A_RBT_31OCT20.pdf34290EDDigital DataDF11/19/2020 Electronic File: MPU_L-21A_RBT_31OCT20_img.tiff34290EDDigital DataDF11/19/2020 Electronic File: MPU_L-21A_RBT_31OCT20_Main.dlis34290EDDigital DataDF11/19/2020 Electronic File: MPU_L-21A_RBT_31OCT20_Repeat.dlis34290EDDigital Data0 0 2200620 MILNE PT UNIT L-21A LOG HEADERS34290LogLog Header ScansDF12/4/202014035 12930 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Main.las34365EDDigital DataDF12/4/202014042 13823 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Repeat.las34365EDDigital DataDF12/4/202014035 12930 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Main.las34365EDDigital DataDF12/4/202014042 13823 Electronic Data Set, Filename: MPU_L-21A_RBT_31OCT20_Repeat.las34365EDDigital DataDF12/4/2020 Electronic File: MPU_L-21A_RBT_31OCT20.pdf34365EDDigital DataDF12/4/2020 Electronic File: MPU_L-21A_RBT_31OCT20_img.tiff34365EDDigital DataDF12/4/2020 Electronic File: MPU_L-21A_RBT_31OCT20_Main.dlis34365EDDigital DataDF12/4/2020 Electronic File: MPU_L-21A_RBT_31OCT20_Repeat.dlis34365EDDigital Data0 0 2200620 MILNE PT UNIT L-21A LOG HEADERS34365LogLog Header ScansTuesday, February 9, 2021AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22629-01-00Well Name/No. MILNE PT UNIT L-21ACompletion Status1WINJCompletion Date11/4/2020Permit to Drill2200620Operator Hilcorp Alaska, LLCMD14109TVD7398Current Status1WINJ2/9/2021UICYesCompletion 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: 11/4/2020Release Date:9/2/2020Tuesday, February 9, 2021AOGCCPage 3 of 3M. Guhl2/9/2021 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/04/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-21A (PTD 220-062) Radial Bond Tool 10/31/2020 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 2200620 E-Set: 34365 Abby Bell 12/09/2020 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _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: 16.70' 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" H-40 112' 7" L-80 5591' 4-1/2" L-80 7398' 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 1396 sx PF 'E', 250 sx Class 'G', 150 sx PF 'E'9-5/8" 40# L-80 Surface 7249' Surface 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, 250 sx Class 'G'8-1/2" TUBING RECORD 90 sx Class 'G' 13720'3-1/2" 9.3# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 9999' 14109' 5535' 4653' 12-1/4" 24" 12.6#6-1/8" 250 sx Arctic Set I (Approx.) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 11/4/2020 1593' FNL, 209' FWL, Sec. 08, T13N, R10E, UM, AK 2256' FNL, 1848' FEL, Sec. 32, T14N, R10E, UM, AK 220-062 Milne Point Field, Kuparuk Oil Pool 49.95' 14,025' / 7,325' HOLE SIZE AMOUNT PULLED 50-029-22629-01-00 MPU L-21A 544806 6031876 2439' FNL, 1858' FEL, Sec. 32, T14N, R10E, UM, AK CEMENTING RECORD 6041608 SETTING DEPTH TVD 6041791 BOTTOM TOP Surface CASING WT. PER FT.GRADE 26# 547925 547935 TOP SETTING DEPTH MD Surface Surface Per 20 AAC 25.283 (i)(2) attach electronic information 10175' Surface DEPTH SET (MD) 13709' / 7051' PACKER SET (MD/TVD) x 2-3/8" 4.7# L-80 91.1# 112' Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST N/A 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 ***Please see attached Schematic for detail*** ROP, ABG, PCG, ADR, ALD, CTN MD & TVD, Cement Evaluation Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: October 26, 2020 10/20/2020 ADL 025509 & 355017 88-002 1800' (Approx.) 10,175' / 5,591'N/A None 14,109' / 7398' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 11:03 am, Nov 19, 2020 RBDMS HEW 11/25/2020 Completion Date 11/4/2020 HEW G DSR-11/25/2020 SFD 11/30/2020 DLB 11/25/2020 MGR03FEB2021 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 13772' 7106' 13499' 6870' 13627' 6981' 13772' 7106' 13781' 7113' 13872' 7193' 13999' 7303' Base Kup 13999' 7303' 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 Kuparuk A Base Kuparuk Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top Kuparuk B Kalubik Kuparuk D 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: Kuparuk C LOT / FIT Data Sheet, Drilling and Completion Reports, Definitive Directional Survey, Csg and Cmt Report, 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 Digitally 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: 2020.11.19 10:12:52 -09'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 11/18/2020 SCHEMATIC Milne Point Unit Well: MPU L-21A Last Completed: 11/5/2020 PTD: 220-062 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112’ 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,249’ 7" Intermediate 26 / L-80 / BTC 6.276 Surface 10,175’ 4-1/2” Liner 12.6 / L-80 / TXP 3.958 9,999’ 14,109’ TUBING DETAIL 3-1/2”x 2-3/8”Tubing 9.3 / L-80 / EUE 8rd 4.7 / L-80 / EUE 8rd 2.441 1.995 Surface 9,965’ 9,965’ 13,720’ JEWELRY DETAIL No Depth Item 1 9,965’ 3-1/2” XO 2-3/8” –MIN ID = 1.970” 2 9,999’ HRD-E HD ZXP Liner Top Packer 3 13,709’ FH Hydrostatic Set SSR Packer 4 13,719’ WLEG –Bottom @ 13,720’ PERFORATION DETAIL Sand TOP MD BTM MD TOP TVD BTM TVD FT Size Date Status Kuparuk C 13,773’ 13,781’ 7,107’ 7,114’ 8’ 2-7/8” 6 SPF 11/1/2020 Open Kuparuk B6 13,781’ 13,836’ 7,114’ 7,161’ 55’ 2-7/8” 6 SPF 11/1/2020 Open Kuparuk A3 13,872’ 13,898’ 7,193’ 7,215’ 26’ 2-7/8” 6 SPF 11/1/2020 Open Kuparuk A2 13,898’ 13,927’ 7,215’ 7,240 29’ 2-7/8” 6 SPF 11/1/2020 Open Kuparuk A1 13,932’ 13,996’ 7,245’ 7.300’ 64’ 2-7/8” 6 SPF 11/1/2020 Open OPEN HOLE / CEMENT DETAIL 24" 250 sx of Arcticset I 12-1/4" 1,396 sx PF “E”, 250 sx Class “G”, 150 sx PF ‘E 8-1/2” 250 sx Class “G” 6-1/8” 90 sx Class “G” WELL INCLINATION DETAIL KOP @ 509’ Max Hole Angle = 79 deg Hole Angle through perforations = 30 TREE & WELLHEAD Tree 3-1/8” – 5M AlloyTree ‘FL’ Wellhead FMC 11” x 11” 5M, Gen 5 w/ 11” x 3.5” FMC Tubing Hanger, w/ NSCT Threads Top and bottom and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22629-01-00 Completed: 11/5/2020 TD =14,109’ (MD) / TD = 7,398’(TVD) 20” Orig.DF Elev.: 49.95’ / GL Elev.: 16.7’ 7” 4 2 3 9-5/8” 1 2 Min ID= 1.970” @ 9,965’ PBTD =14,025’ (MD) / PBTD = 7,326’(TVD) Howco ES Cementer @ 2,132’ 4-1/2” 3-1/2” XO 2-3/8” @ 9,965’ WINDOW DETAIL Top of Window – 10175’ (5591’ TVD)’, Bottom of Window – 10186’ Inclination 72.26 deg TOWS 10,175' est TOC 13,590' MD CASING AND LEAK-OFF FRACTURE TESTS Well Name:MPU L-21A Date: Csg Size/Wt/Grade:7"40# x 26#, L-80 Supervisor:Sunderland/Vanderpool Montague Csg Setting Depth:10186 TMD 5594 TVD Mud Weight:9 ppg LOT / FIT Press =786 psi . LOT / FIT =11.70 ppg Hole Depth =0 md Fluid Pumped=1.1 Bbls Volume Back =1.1 bbls Estimated Pump Output:0.101 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->00 ->00 ->1165 ->5206 ->2271 ->10 498 ->3325 ->15 795 ->4389 ->20 1083 ->5450 ->25 1340 ->6511 ->30 1633 ->7566 ->35 1886 ->8629 ->40 2246 ->9686 ->45 2523 ->10 746 ->48 2640 ->11 799 -> ->12 -> ->13 -> Enter Holding Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0799 ->0 2640 ->1745 ->5 2628 ->2729 ->10 2618 ->3720 ->15 2612 ->4710 ->20 2608 ->5704 ->25 2607 ->6699 ->26 2607 ->7694 ->27 2606 ->8690 ->28 2606 ->9686 ->29 2606 ->10 682 ->30 2605 ->11 678 -> ->12 675 -> ->13 671 -> ->14 668 ->15 665 ->16 662 10/18/2020 & 10/20/2020 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 1020304050Pressure (psi)Strokes (# of) LOT/FIT Casing Test 799 745729720710704699694690686682678675671668665662 2640 2628 2618 2612 2608 260726072606260626062605 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 30 35Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 10/15/2020 Notified AOGCC of upcoming BOP Test @ 05:54 on 10/15/2020, Move Rockwasher and finish prep rig for move. PJSM, Skid rig floor into moving position, move Rig off L-63 and park Rig at NW end of pad. Remove BOP Ram blocks for inspection & re-certification. Install new 2-7/8”x5” VBR, Blind rams & 2nd set of 2-7/8”x5” VBR’s. Remove two segment links from #1 drag chain. SimOps: HES slick line work on L-63. Move rig matts and clear area behind L-21 Well head. Start pad prep around Well. 10/16/2020 Wait on slickline and Tie-in work on L-63. Dress rig floor drillpipe handling equipment for 4" DP. Prep pad area around L-21 & set matting boards for Rig footprint. Spot tree behind L-21 Wellhead and perform general housekeeping around rig.,PJSM, Move Rig from staging area and spot over L-21. Level and shim rig then skid Rig floor into drilling position.,Work on rig acceptance checklist, spot rockwasher & fuel trailer. Spot flow back tank. Wells support crew rig up 2" hardline from Rig to tank. Rig accepted at 03:00. Finish hardline from Rig to flow back tank. Rig up in cellar to take returns from IA to tank. Check pressure on IA and Tree - 0 psi.,PJSM, Mobilize Cameron S10 lubricator to rig floor, install on Tree and test. Pull BPV and R/D lubricator. SimOps: Put steam on line from Cellar to flow back tank. 10/17/2020 Rig up lines to pump down tubing. Cover and secure cellar box with pit liner. Rig up tank farm to transfer fluid to Rig,PJSM to ciculate out freeze protect. Test high pressure lines 250 psi/3000 psi. Good. Pump 280 bbls 125° KCl brine with DeepClean added, 6 BPM – 2150 psi, 30 bbls Hi-Vis spacer 4 BPM – 810 psi and chase with 500 bbls 9.0 ppg brine 6 BPM – 2400 psi. Clean brine returns.,Monitor well – Static -. Blow down and rig down lines. Wellhead Rep set BPV.,N/D Tree. Test run crossover to tubing hanger. 7 turns to seat – Good. Stand Trees up out of way in cellar and secure,N/U BOPE stack. Weld additional 4’ section to trip nipple and install.,Flood stack and check for leaks. Run 3.5” test joint w/ donut spaced out at Annular. Flood choke and purge air from system. Attempt 4k shell test. Test hose appears to have blockage – replace hose. Purge air and shell test BOPE 250 psi/ 4000 psi, 5 min each.,Test BOP equipment as per AOGCC to 250 PSI low / 4000 PSI high. Tests held for 5 min each & charted. AOGCC inspector Robert Noble on-site to witness test. All tests performed with fresh water against a BPV test dart. Perform accumulator draw down. Test gas alarms and PVT. Monitor IA in Cellar.,1. Annular on 3.5" test joint, choke valves 1, 12, 13, 14, Kill Demco & 4” FOSV. 2. Upper 2.875"x5" VBR on 3.5” test joint, choke valves 9, 11, HCR kill & 4" dart valve. 3. Choke valves 5, 8, 10, Manual Kill & 3.5” FOSV. 4. Choke valve 4, 6, 7, & 3.5” dart valve. 5. Choke valve 2. 6. HCR choke. 7. Lower 2.875"x5" VBR on 3.5” test joint. 8. Upper 2.875"x5" VBR on 4.5” test joint, manual choke & lower IBOP,9. Lower 2.875"x5" VBR on 4.5” test joint & upper IBOP. 10. Blind Rams & choke valve 3 - Failed. 11. Manual choke A. 12. Manual choke B. Perform Accumulator test: 3080 psi sys pressure, 1675 PSI after closure, 200 PSI recovery in 38 sec, full recovery in 191 sec, 6 N2 bottle avg = 2142 PSI.,Trouble shoot and start repairs on choke valve 3.,H2O from L-Pad: 475 bbls Daily/ 475 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 180 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 680 bbls Daily / 680 bbls Total. 10/18/2020 Rebuild choke valve #3. Re test to 250/4000 psi. Good. R/D Testing equipment.,Suck out stack with rig vac. Pull TWC. Well static.,M/U 4'' Landing joint with NWCT XO. M/U to hanger. 7.5 Turns. M/U TD. BOLD, Pull hanger off seat at 92K up, 95K free wt. with tubing. Pull hanger to rig floor & L/D same. R/D landing joint.,R/U 3.5" Tongs and change handling equipment to 3.5". POOH f/ 11985' t/ surface. Total of 381 full joints and a 9' cut joint of 3-1/2" 9.3#, L-80, NSCT tubing pulled. Total of 12.013.76', 3-1/2" tubing pulled out of hole.,Rig down casing handling equipment, clear and clean rig floor. Set wear ring - 7 1/8" ID,Rig up test equipment. Purge air from system and test 7" casing against blind rams t/ 2500 psi for 30 minutes, charted. Good test. Rig down test equipment and blow down lines.,Mobilize 7" casing clean out assembly components to Rig floor.,Hold PJSM on making up BHA. Make up 7" casing clean out assembly. 6-1/8" Hughes STX-1 Milltooth bit, WIS 7" casing scraper, 2x WIS 5" boot baskets, bit sub w/ ported float, WIS 4-3/4" oil jar, 9x 4-3/4" drill collars & 21x 4" HWDP t/ 959',RIH with 7" casing clean out assembly, picking up 4" drillpipe singles f/ 959' t/ 2695'. 4" drillpipe drifted to 2.35",H2O from L-Pad: 90 bbls Daily/ 565 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 680 bbls Total. 10/19/2020 Continue RIH with 7” scraper assembly, picking up 4” drillpipe singles f/ 2695’ t/ 10247’. Pipe drifted to 2.573”. 140k PU / 100k SO,Displace Wellbore f/ 9.0 ppg brine to 9.0 ppg LSND. 340 GPM – 1400 psi. Rotate and reciprocate string f/ 10247’ t/ 10148’ the duration of displacement. 20 RPM – 5k Tq,Pump dryjob, 1.5 ppg over, and blow down TopDrive.,POOH f/ 10247’ t/ 7773’ Racking drillpipe, HWDP and drill collars in Derrick. Swap to Drilling AFE @ 18:00,See MPU L-21A Drilling Report for details. H2O from L-Pad: 20 bbls Daily/ 585 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 214 bbls Daily / 894 bbls Total. 10/19/2020 POOH with 7” scraper assembly f/ 7773’ t/’ 31’ Racking drillpipe, HWDP and drill collars in Derrick. Break down scraper BHA. Empty and flush boot baskets – no debris captured in baskets. Clear and clean rig floor. SimOps: Test MPD lines 250/1300 psi. -Good. M/U Whipstock assembly. UBHO sub, float sub w/ ported float, TM collar, DM collar. Shallow pulse test MWD – good. Make up BHA, MCBPV, 1x Jt HWDP, running tool and tri-mill assembly. Scribe to MWD DM & UBHO. Mate up to WIS 7” casing hydraulic TrackMaster Whipstock. - 35k Shear bolt. RIH with 3 stds drill collars & 7 stds HWDP t/ 1024'. Continue in hole with stds 4" drillpipe t/ 3393'. 45'/min running speed. Fill pipe on the fly with fill hose and top off every 5 stands. H2O from L-Pad: 20 bbls Daily/ 585 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 214 bbls Daily / 894 bbls Total. 10/20/2020 Continue trip in hole with Whipstock/Milling assembly on 4" drillpipe stands f/ 3393' t/ 10195'. 141k PU / 106k SO Establish circulation, work string 15’ while orient Whipstock to 172° right of HS. 250 GPM, 1380 psi. Cycle pumps 6x total, closing bypass valve. Pressure up to 3400 psi and set Whipstock anchor. Pressure drop down t/ 2600 psi. and falling. Engage pump @ 1 BPM – 3100 psi, getting returns. Maintain pressure with the 1 BPM & work Dn/Up 75k/160k several times. Shear Mill from slide 4th stroke dn. 33k to shear bolt. P/U & observe psi drop t/ 1700 psi- Anchor hyd line parting. Mill window f/ TOW =10175’ t/ BOW =10186’. 100 RPM, 6-7k Tq. 168 GPM, 1400 psi. 4-8k WOB. Continue drilling/milling t/ 10206', cutting 20' new hole past BOW. Dress window 3x, 60 RPM, 4k Tq. 168 GPM, 1300 psi., then work through with no rotary and again with no pumps/rotary - Clean. Total of 69.5# metal recovered at shakers and magnets. Circulate 30 bbl hi-vis sweep around and hole clean. 250 GPM, 2100 psi. 10 RPM, 3k Tq. Work string 90’. Minimal increase in cuttings with sweep to surface. Blow down TopDrive, Rig up testing equipment and lines. Close UPR &perform FIT t/ 11.7 ppg EMW with 9.0 ppg MW at 5594’ TVD. Pressure up to 786 psi, 1.1 bbls pumped, 1.1 bbls bled back. Blow down lines and rig down test equipment Lay down 2x singles of 4" drillpipe t/ 10124'. Cut & Slip 74' drilling line. Service Topdrive, draworks and iron roughneck. Re-calibrate block height. POOH with milling assembly f/ 10124' t/ 4750'. Rack stands in Derrick. Daily Loss = 0 bbls, Cumulative losses = 0 bbls. H2O from L-Pad: 90 bbls Daily/ 675 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 894 bbls Total. 50-029-22629-01-00API #: Well Name: Field: County/State: MP L-21A Milne Point Hilcorp Energy Company Composite Report , Alaska 10/21/2020 Continue to POOH with milling assembly from 4750' to 1004'. Monitor well, static. L/D excess HWDP and drill collars, rack back jar stand and 1 stand HWDP. L/D milling assembly, lower and middle mill 1/8" under gauge, upper mill 1/16" under gauge. Clear rig floor. Pull wear bushing. Pick up stack washing tool and flush stack. Blow down top drive, kill and choke line. set wear bushing. M/U kick-off BHA, NOV PDC, SperryDrill mud motor with 1.5° bend, float sub, DM collar, TM collar. Measure RFO = 2.14/4.8 = 160.5°, float sub, (3) flex collars, XO, (2) HWDP, Jars, (3) HWDP. Shallow pulse test MWD. Pick up, drift (2.573") and single in the hole with 4" drillpipe from 338' to 5168', fill pipe every 20 stands. Continue TIH w/ stds 4" DP f/ 5168' t/ 10178'. fill pipe every 20 stands. Tag up 5k attempting to exit window on elevators. Pull above slide and Kelly up. 140k PU / 105k SO Bring on pumps, 250 GPM & orient motor TF @ 160 L of HS. Shut pumps down, slack off and exit window with no issues. Tag bottom on depth at 10206'. Drill 6-1/8” hole f/ 10206' t/ 10332' (5653' TVD) 126' drilled, 23/hr AROP. 250 GPM, 2140 psi, 60 RPM, 7k Tq, 8- 15k WOB. MW in/out 9.0/9.0, vis in/out 55/50. Max gas 32u. 126k PU / 92k SO / 100k ROT. Sliding first 44’ at low side TF for separation before rotating ahead. Survey at 10241.20’ had an INC of 65.62°. The 74’ survey CL showed a 9°/100’ DL coming off the whipstock. Calculated 4.12’ of separation from the parent Wellbore at 10241’. Metal Recovered: Daily (Midnight)= 7.2 lbs / Cumulative=76.7 lbs. Interval Daily (Midnight) Loss= 0 bbls / Cumulative losses=0 bbls H2O from L-Pad: 30 bbls Daily/ 705 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 50 bbls Daily / 944 bbls Total. 10/22/2020 Pump out of hole from 10,332' to 10,097' at 240 gpm, 1950 psi. Shut pumps off when pulling motor through window. No issue going through window. Circulate bottoms up at 240 gpm, 1950 psi, 40 rpms, 5Kft-lbs, reciprocating pipe. Blow down top drive. Monitor well, static. POOH from 10,097' to 9.434', no indication of swabbing. Pump dry job, blow down lines. Continue to POOH to 336'. Monitor well at BHA, static. Rack back HWDP stand, HWDP/Jar stand, and DC. L/D BHA. Bit grade 1-1-BU-A-I-PN-BHA. Junk slot area between two blades tightly packed off with clay. Clean and clear rig floor. M/U RSS drilling assembly: NOV TK56 PDC bit, Geo-Pilot 5200, DM collar, Gamma collar, ILS, ADR collar, PWD collar, CTN-ALD collar, TM collar, ILS, float sub. Plug in and upload MWD. M/U XO and shallow hole test MWD - Good. Load sources and RIH w/ non mag collars, HWDP & jars t/ 401' TIH with 6.125" RSS drilling assembly f/ 401' t/ 10159'. Fill pipe every 20 stds. Break in RSS seals & disable manual steering mode @ 2500'. Install split bushings. Remove trip nipple. Install MPD rotary head. Install drip pan on stack. Install hoses from drip pan to containment drums in cellar. Flood MPD lines from stack to flow line and check for leaks. Install skirt from rig floor pollution pan to MPD drip plan and secure. Service Rig, Change out Bell Guide on TopDrive t/ 4" guide, tool joints hanging up on 5" bell guide when kellying up. SimOps: Finish install skirt at MPD bearing. RIH t/ 10258’, see 5-10k increase in drag with BHA going through window. Wash down f/ 10258’ t/ 10332’ tagging bottom on depth, 240 GPM – 1800 psi. Drill 6-1/8” hole f/ 10332' t/ 10372' (5669' TVD) 40' drilled, 26.66/hr AROP. 250 GPM, 2140 psi, 120 RPM, 8k Tq, 8-10k WOB. MW in/out 9.0/9.0, vis in/out 54/59. Max gas 33u. 130k PU / 90k SO / 115k ROT. Build and turn, target 4° DLR Metal Recovered: Daily (Midnight)= 27 lbs / Cumulative=103.7 lbs. Interval Daily (Midnight) Loss= 12 bbls / Cumulative losses= 12 bbls H2O from L-Pad: 75 bbls Daily/ 780 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 114 bbls Daily / 1,058 bbls Total. 10/23/2020 Drill 6-1/8” hole f/ 10372' t/ 10565' (5745' TVD) 193' drilled, 32fph AROP. 250 GPM, 2050 psi, 120 RPM, 8k Tq, 7k WOB. ECD 11.0 ppg, MW in/out 9.0/9.0, vis in/out 55/56. Max gas 217u. 137k PU / 85k SO / 112k ROT. Build and turn, target 4° DLR Pump nut plug bit balling sweep at 10,410 with slight increase ROP from 30-50 fph to 60-100 fph. Drill 6-1/8” hole f/ 10565' t/ 10872' (5850' TVD) 307' drilled, 51 fph AROP. 250 GPM, 2040 psi, 140 RPM, 8k Tq, 13k WOB. ECD 11.0 ppg, MW in/out 9.0/9.0, vis in/out 50/52. Max gas 216u. 135k PU / 92k SO / 112k ROT. Build and turn, target 4° DLR. Pump bit balling sweep at 10,610 with minimal increase Drill 6- 1/8” hole f/ 10872' t/ 11252' (5925' TVD) 380' drilled, 63.33fph AROP. 250 GPM, 2090 psi, 160 RPM, 9k Tq, 9k WOB. ECD 11.1 ppg, MW in/out 9.0/9.0, vis in/out 45/48. Max gas 126u. 137k PU / 85k SO / 112k ROT. Build and turn, target 4° DLR t/ 10896’ Drill 6-1/8” hole f/ 11252' t/ 11716' (6013' TVD) 464' drilled, 77 fph AROP. 200 GPM, 1770 psi, 160 RPM, 9k Tq, 7-10k WOB. ECD 10.87 ppg, MW in/out 8.95/9.0, vis in/out 45/47. Max gas 126u. 140k PU / 85k SO / 120k ROT. Hold 78.71° tangent. Pump tandem sweeps at 11583’. Back on time, with no increase Well took 10 bbls losses while backreaming connection @ 11582’, loss rate calculated at 120 bbls/hr. 250 GPM. Slow flow rate down to 220 GPM after connection, losses reduced to 17 bbls/hr. Slow pumps further t/ 200 GPM, losses down to seepage. MPD Pressure start building on shut in choke during connections t/ 250 psi. Indications of breathing. Last survey @ 11655.55' MD / 6001.63' TVD, 78.87° inc, 5.23° azm, 3.63’ from plan, 2.04' high, 3.01' right. Metal Recovered: Daily (Midnight)= 44.5 lbs / Cumulative=148 lbs. Interval Daily (Midnight) Loss= 0 bbls / Cumulative losses= 12 bbls H2O from L-Pad: 520 bbls Daily/ 1,300 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 513 bbls Daily / 1,571 bbls Total. 10/24/2020 Drill 6-1/8” hole f/ 11716' t/ 11817' (6031' TVD) 101' drilled, 67 fph AROP. 200 GPM, 1810 psi, 160 RPM, 10k Tq, 8k WOB. ECD 10.78 ppg, MW in/out 8.95/9.0, vis in/out 43/47. Max gas 217u. 145k PU / 80k SO / 105k ROT. Seepage losses at 200 gpm, At 11,770' temporary Increase flow to 220 bph to downlink. Observe losses increase, slow rate to 200 gpm. Loss rate at 90 bph. Slow rate to 180 gpm with 60-80 bph loss rate. Pick up off bottom and slow rate to 140 gpm with minimal losses. Mix and pump 27 bbls LCM pill with 10 ppb each: Safecarb 20, 250, and 750. Pump pill to bit and increase pump rate to 210 gpm, 1580 psi, 120 rpms, 6K ft-lbs. Dynamically squeeze 14 bbls of pill. Rack back 1 stand. Well breathing back on connection initial MPD rate 174 gpm falling to 149 in 5 minutes. Shut chokes, pressure build to 350 psi. CBU at 140 gpm to 190 gpm (36 bph loss), 95U of gas at bottoms up (~30U BGG). Pump second LCM pill with same carbonate concentration as previous and 10 ppb Asphasol, increase pump rate to 210 gpm as pill rounds the bit and dynamically squeeze 10 bbls into formation. Circulate at 190 gpm with 25 bph loss rate. M/U stand and RIH to bottom. During connection allow well to breathe for 2.5 minutes, initial flow 196 gpm, slowing to 186 gpm. Shut in and pressure build to 350 psi. bottoms up returned 196U gas. Drill 6-1/8” hole f/ 11817' t/ 12088' (6090' TVD) 271' drilled, 41.7fph AROP. 190 GPM, 1650 psi, 130 RPM, 9k Tq, 5-10k WOB. ECD 10.7 ppg, MW in/out 8.95/9.0, vis in/out 45/46. Max gas 154u. 148k PU / 88k SO / 120k ROT. Hold 78.71° tangent. Losses @ 10-23 BPH Drill 6-1/8” hole f/ 12088' t/ 12352' (6145' TVD) 264' drilled, 44fph AROP. 180 GPM, 1740 psi, 120 RPM, 8k Tq, 10k WOB. ECD 10.8 ppg, MW in/out 8.9/9.0, vis in/out 41/46. Max gas 94u. 153k PU / 87k SO / 110k ROT. Start 4°/100’ drop @ 12246’. Reduce flow t/ 180 GPM @ 12270'. Loss rate drop t/ 0-3 BPH Drill 6-1/8” hole f/ 12352' t/ 12543' (6214' TVD) 191' drilled, 31.8fph AROP. 190 GPM, 1650 psi, 140 RPM, 9-12k Tq, 8-12k WOB. ECD 10.8 ppg, MW in/out 8.9/9.0, vis in/out 41/47. Max gas 64u. 155k PU / 90k SO / 115k ROT. Continue 4°/100’ drop. Loss rate @ 1-7 BPH Pump 25 bbls low vis SAPP/Bit cleaning pill @ 12445’. Metal Recovered: Daily (Midnight)= 0 lbs / Cumulative=148 lbs. Interval Daily (Midnight) Loss= 337.5 bbls / Cumulative losses= 349.5 bbls. Last survey @ 12508.26' MD / 6199.53' TVD, 66.15° inc, 6.63° azm, 4.37’ from plan, 3.29' high, 2.88' Left. H2O from L-Pad: 550 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 140 bbls Daily / 140 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 513 bbls Daily / 2,084 bbls Total. 10/25/2020 Drill 6-1/8” hole f/ 12543' t/ 12771' (6329' TVD) 228' drilled, 38fph AROP. 170 GPM, 1670 psi, 140 RPM, 6k Tq, 8-10k WOB. ECD 10.8 ppg, MW in/out 8.9/9.0, vis in/out 41/47. Max gas 64u. 145k PU / 97k SO / 115k ROT. Loss rate @ 5-10 BPH. Hold 350 psi on connections (10.11 ppg EMW) Add 0.25% Lube 776, observe torque drop from 13-14Kft-lbs to 7Kft-lbs Drill 6-1/8” hole f/ 12771' t/ 12922' (6419' TVD) 151' drilled, 25.17/hr AROP. 170 GPM, 1700 psi, 150 RPM, 6k Tq, 5-12k WOB. ECD 10.9 ppg, MW in/out 8.9/9.0, vis in/out 43/52. Max gas 33u. 148k PU / 97k SO / 120k ROT. Loss rate @ 5-20 BPH. Hold 325 psi on connections (9.97 ppg EMW). Continue with 4°/100’ drop rates. Pump 30 bbls low vis SAPP/ScreenKleen Bit cleaning pill @ 12859’ Drill 6-1/8” hole f/ 12922' t/ 13185' (6609' TVD) 263' drilled, 43.83/hr AROP. 180 GPM, 1810 psi, 140 RPM, 7k Tq, 5-10k WOB. ECD 11.02 ppg, MW in/out 9.0/9.0, vis in/out 44/51. Max gas 95u. 155k PU / 100k SO / 125k ROT. Loss rate @ 2-15 BPH. Continue with 4°/100’ drop rates. Hold 325 psi on connections (9.95 ppg EMW) Drill 6-1/8” hole f/ 13185' t/ 13461' (6838' TVD) 276' drilled, 46/hr AROP. 210 GPM, 1830 psi, 145 RPM, 9k Tq,7-9k WOB. ECD 10.76 ppg, MW in/out 9.0/9.05, vis in/out 40/46. Max gas 187u. 165k PU / 105k SO / 125k ROT. Loss rate @ 0-5 BPH with some breathing Maintain 0.75% lubes. Continue with 4°/100’ drop rates. MPD full open while drilling. Hold 325 psi on connections (9.95 ppg EMW) Start adding 290 bbls black product, (Asphasol Supreme & Resinex @ 11 ppb), spike fluid at 13225’. ECD’s drop from 10.97 ppg to 10.8 ppg. Well breath back 20 bbls over 2 hrs before equalizing. 65u gas with BU, 95u Max. Increase MPD pressure to 385 psi (10.1 ppg) at 13380' connection. Metal Recovered: Daily (Midnight)= 18 lbs / Cumulative=174 lbs. Interval Daily (Midnight) Loss= 115 bbls / Cumulative losses= 464.5 bbls. Last survey @ 13361.38' MD / 6754.32' TVD, 33.18° inc, 3.09° azm, 7.29’ from plan, 6.83' low, 2.54' Left. H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 580 bbls Daily / 720 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 456 bbls Daily / 2,540 bbls Total. 10/26/2020 Drill 6-1/8” hole f/ 13461' t/ 13615' (6970' TVD) 154' drilled, 26/hr AROP. 205 GPM, 1740 psi, 160 RPM, 7k Tq,4-12k WOB. ECD 10.78 ppg, MW in/out 9.0/9.05, vis in/out 40/46. Max gas 278u. 175k PU / 106k SO / 128k ROT. Minimal seepage losses, with breathing back At 13,600 - 13,645' observe multiple 200 psi packoffs at bit, pick up off bottom, and ease back down. Adjust parameters, increasing flow to 220 gpm, then down to 175 gpm lower WOB. MPD attempt to hold 425 psi (~10.2 ppg EMW at Kalubik)on connections, observe pressure bleed down to 415 psi. Drill 6-1/8” hole f/ 13615' t/ 13777' (7110' TVD) 162' drilled, 27/hr AROP. 180 GPM, 1510 psi, 140 RPM, 7k Tq,5-12k WOB. ECD 10.5 ppg, MW in/out 9.0/9.05, vis in/out 40/46. Max gas 248u. 185k PU / 108k SO / 132k ROT. Minimal losses, and breathing. Drill with MPD open, attempt to hold 425 psi on connections, bled down to 365 psi. Drill 6-1/8” hole f/ 13777' t/ TD @ 14109' (7398' TVD) 332' drilled, 55.33fph AROP. 175 GPM, 1440 psi, 140 RPM, 8k Tq, 11k WOB. ECD 10.44 ppg, MW in/out 9.0/9.1, vis in/out 39/47. Max gas 428u. 190k PU / 110k SO / 140k ROT. Maintain 30° tangent. No losses, Wellbore breathing. Drill with MPD open, attempt to hold 425 psi on connections, bleeding down to 371 psi. Top of Kup C Sand @ 13772'. Kup A Base @ 14002'. TD in the Miluveach Take final survey & pump 30 bbl hi vis sweep. BROOH f/ 14109’ t/ 13955’ while circulate sweep around and hole clean with 2.5x BU. Sweep back 300 stks late w/ 20% increase. Max Gas = 337u. Blow down TopDrive &Line up Rig pump to MPD lines. Stage pump up to 230 GPM, 1030 psi POOH on elevators 20’-30’/min f/ 13955' t/ 11868'. MPD holding CBHP @ HRZ w/430 psi static & 675 psi dynamic backpressure on Well. Pulled 25k over @ 13770’. (Bottom of Kup D Shale @ 13772'). No other issues while pulling Metal Recovered: Daily (Midnight)= 11 lbs / Cumulative=185 lbs. Interval Daily (Midnight) Loss= 0 bbls,- Wellbore breath - / Cumulative losses= 464.5 bbls. Last survey @ 14086.23' MD / 7398.3 TVD, 29.51° inc, 2.63° azm, .98’ from plan.97' low, .17' Left. H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 740 bbls Daily / 1,460 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 855 bbls Daily / 3,395 bbls Total. 10/27/2020 Cont. POOH for wiper trip from 11868’, pull tight at 10,520’ (20K) work pipe once. Continue to POOH holding 650 psi dynamic and 400 static pressure, 30 fpm as per adjusted MPD, Pulled tight from 10,340’(35K) to 10,302’ (top Stab at window at 10,302), work pipe until clean up to the top stab at 10,302’. Discussed with engineer, decided not to pull BHA through window on wiper trip. RIH to 10,535’ to get HWDP across window. RIH to 10,535’ to get HWDP across window. Circulate surface to surface at 215 gpm/1450 psi, 130 rpms, 5.7Kft-lbs. RIH from 10,535' as per MPD 30 fpm adjusting to holding 200 psi dynamic and 400 psi static. Set 35K down at 13,560 and 13,590’ (within the Kalubik), work through with no pumps rotary. Attempt to wash last stand down at 2 bpm, set down at 14,097 (Kup A1 base/Miluveach at 14,002’), increase flow to 170 gpm to wash through unable to. Wash and ream to bottom at 100 rpms, 170 gpm. Shut down pumps and trap 300 psi with MPD, built and stabilized at 327 psi. Pump high viscosity sweep (20% increase, 200 strokes late) at 190 gpm, 1530 psi, 50 rpms, 5.5Kft-lbs Pump and Spot 144 bbls 10.2 ppg liner running pill at 207 gpm slowing to 176 gpm, 1457 psi as ECD's increase. Final ECD 10.52 ppg EMW. Blow down top drive. Pressure stabilized at 279 PSI after 10 min while lining up injection line for backpressure. POOH on elevators f/ 14,109' while holding 370 PSI static & 520 PSI dynamic backpressure. Adjusted to 400 static & 560 dynamic. Observe 20-25K intermitted drag f/ 13,732' t/ 13,673' which fell off each time. Observe 30K drag at 10,325' (drill collars at window), but no drag with stabs or bit as BHA was pulled to 10,161'. Losses on trip out of the hole - 4.1 bbls. Service rig, grease top drive and rig floor equipment. Sim-ops: prep pits for brine displacement. Hold 400 PSI back pressure with MPD = 10.3 ppg EMW - static. Continue to prepare the mud pits for displacement. Load 10.2 ppg from trucks into pit #5 and build high vis spacer. Hold 370 PSI back pressure with MPD = 10.2 ppg EMW - static. Hold PJSM for displacement with rig crew, mud man, MPD and DSM. Pump 18 bbls of high vis spacer then displace to 10.2 ppg brine. 220 GPM, 1280 PSI initial, slowing to final 180 GPM, 880 PSI to keep ECD at 11.5 ppg with MPD choke full open. Rotate 30 RPM, 4K TQ, 130K PU / 105K SO / 115K ROT. Spacer back on time w/ 40 bbls interface. Install FOSV & 4" pup joint. Slip & cut 73' of drilling line. Sim-ops: monitor well with MPD. Initial breathing of 230 BPH slowed to 82.8 BPH in 10 min. Shut choke observe 45 PSI. Monitor breathing from 67.2 BPH to 17.4 BPH in 10 min. Shut choke observe 28 PSI. Monitor breathing from 17.14 BPH to 7.43 BPH in 10 min. Shut choke observe 21 PSI. Monitor breathing from 12.86 BPH to 4.29 BPH in 20 min. Shut choke observe 19 PSI. Monitor breathing from 4.99 BPH to 2.84 BPH. Shut choke observe 16 PSI. Open choke - no flow shown on MPD flow meter. Close choke observe no pressure. 29.2 bbls returned. Open 2" valve on MPD head and visually monitor flow. Initial 3.96 BPH slowed to 2.98 BPH in 30 min. with 1.94 bbls returned. Shut choke and observe 12 PSI static hydrostatic build to 14 PSI. Continue to monitor through 2" valve, from 3.15 BPH to final 0.75 BPH and still slowing after an hour. 5.5 bbls daily losses / 417.8 bbls cumulative losses. H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 295 bbls Daily / 1,755 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 746 bbls Daily / 4,141 bbls Total. 10/28/2020 Drop 2.35" drift. POOH with 4" drill pipe from 10,161' to 687'. MPD hold 30 psi dynamic, wide open on connections. Initial pull speed 30 fpm, increasing to 90 fpm. Calculated displacement for trip 56 bbls, actual 65.5 bb.s Monitor well through MPD 2" on stack. Initial flow back 5.5 BPH, slowing to 0.8 BPH in 80 minutes. Pull MPD RCD bearing, install trip nipple. Monitor well - static. Cont. to POOH f/ 687' t/ 403'. Drift on top of first joint of HWDP. POOH laying down BHA to 112'. Unload sources. Read MWD. L/D remainder of BHA f/ 112'. BHA components in good condition. Bit had a broken blade, graded 1-8-BC-N-X-I-NR-TD. 10 bbls lost on trip. 2 BPH losses while laying down BHA. Clear rig floor of BHA components. Mobilize casing equipment to the rig floor and rig up Doyon double stack tongs, slips and XO on FOSV. PJSM w/ rig crew, Doyon casing, Baker reps, mud man & DSM. 1 BPH static losses. M/U 4-1/2" round nose float shoe, joint #1, float collar, joint #2, landing collar, joint #3 &4 to 164'. Thread lock first 3 connections & torque to 6200 ft/lbs. Check floats - good. Installed two 5.75" hydro-formed centralizers on joint #1, one each on jts #2 to #4. 8 stop rings total on jts #1-3. Run 4-1/2" 12.6# TXP-BTC SR L-80 liner f/ 164' t/ 4071'. Install 5.75" hydro-formed centralizers on jts #5-24. Torque connections to 6200 ft/lbs. Fill w/ 10.2 ppg brine on the fly & top off every 10 jts. Start @ 30'/hr increasing to 70'/hr. 5 bbls losses, consistent w/ 1 BPH static losses. Total of 100 joints of 4-1/2" liner, 25 centralizers and 8 stop rings ran. M/U Baker 5"x7" HRD-E HD ZXP liner top packer to 4115'. Hanger set w/ 6 pins - 2,139 PSI shear. Packer set w/ 5 pins - 24,500 lbs shear. Fill tie-back with PAL max. 80K PU / 78K SO TIH w/ 4-1/2" liner on 4" drill pipe stands from the derrick f/ 4115' two stands t/ 4305'. Circulate 19 bbls to ensure good flow path. 2 BPM = 90 PSI, 3 BPM = 125 PSI, 4 BPM = 160 PSI, 5 BPM = 220 PSI. Blow down top drive. 12.5 bbls daily (midnight) losses, 424.3 bbls cumulative losses H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 85 bbls Daily / 1,840 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 325 bbls Daily / 4,466 bbls Total. 10/29/2020 TIH w/ 4-1/2" liner on 4" drill pipe f/ 4305' t/ 8663' at 90'/min. Correct displacement to stand #45 but then began to surge the formation and observe breathing on next three connections to stand #48 (8663'). PJSM w/ Doyon, Beyond and DSM for installing MPD. Remove trip nipple and install RCD. Line up MPD for returns through open chokes. TIH w/ 4-1/2" liner on 4" drill pipe f/ 8663' t/ 10083' with 30-90'/min running speed. Displace 10.2 ppg brine inside the 7" casing from 10083' with 9.0 ppg LSND mud. Pump 15 bbls high vis spacer followed by 403 bbls mud. 2.5 BPM, 530 PSI ICP, 630 PSI FCP. 418 bbls pumped, 410 bbls returned. 120K PU / 92K SO. Continue to TIH w/ 4-1/2" liner on 4" drill pipe f/ 10083' to 12073' at 30-90'/min running speed. Fill pipe on the fly & top off every 5 stands. Hold 10.2 ppg EWM via MPD w/ 350 PSI static and 150 PSI dynamic. 120K PU / 92K SO, nothing observed through window at 10175'. Displace out 1/2 of the liner running pill at 12073'. stage up to 140 GPM, 630 PSI PSI monitor flow in/out & reduce flow to 120 GPM, 700 PSI as 10.2 ppg liner running pill enters more vertical hole. 359 bbls pumped, 332 bbls returned. 140K PU / 90K SO. Continue to TIH w/ 4-1/2" liner on 4" drill pipe f/ 12073' to 13590' at 30'/min running speed. Fill pipe on the fly & top off every 5 stands. Hold 10.2 ppg EWM via MPD w/ 380 PSI static and 190 PSI dynamic. Liner took 50K weight at 13590', P/U & overpull 40K on two attempts. Est. circulation at 3 BPM, 740 PSI. Slack off, took 35K & pressure up at 13591'. P/U to 13583 pulled 35K over then free & pressure dropped. Work pipe multiple times f/ 13591' t/ 13583' before obtain free movement. Est rotation @ 20 RPM, 5K TQ, 140K PU / 90K SO /120K ROT (torque limit set @ 6K). Slack off & observe pressure increase & rotary stall. P/U to free & increase torque limit to 7K. Slack off pressure up & stall again. P/U & break over free. Work down w/ rotation slowly to 13604'. Begin speeding up to 2'/min. Packed off & stalled at 13608'. Work free & stage up pumps to 0.5, 1.0, 2.0 BPM with 30% to 50% losses. Work down to 13610'. Shut down pumps & work liner down to 13644' with 40-50K WOB then tripped freely. 160K PU / 95K SO. Continue to TIH w/ 4-1/2" liner on 4" drill pipe f/ 13644' t/ 14095'. Hold 10.2 ppg EWM via MPD w/ 380 PSI static and 190 PSI dynamic. Stage up pumps to 3 BPM, 790 PSI and circulate remainder of 10.2 ppg liner running pill. Reciprocate pipe f/ 14095' t/ 14061. Max gas 2205u. Losses fluctuated f/ 22-52 BPH. 88 bbls total lost. Attempt to stage up to 5 BPM, packed off at 4.7 BPM. Re-establish circulation at 3 BPM, 750 PSI, 20 RPM, 6K TQ. Wash down slowly f/ 14095' t/ 14109'. Increase flow rate to 4.2 BPM, 950 PSI. Backream stand to 14060'. No losses once heavy pill out of the hole. 9.2 ppg in / 9.25 ppg out. Blow down top drive. P/U 4.48' pup joint, 15.62' pup joint & 31.47' single to space out. M/U Baker cement head with 10' handling joint on top. R/U cement lines. Daily (midnight losses) = 28 bbls, Cumulative losses = 452.3 bbls Total H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 80 bbls Daily / 1,920 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 0 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 620 bbls Daily / 5,086 bbls Total. 10/30/2020 Finish rigging up and securing cement lines. Maintain 420 PSI backpressure via MPD to maintain 10.35 ppg EMW at Kuparuk C. Stage up with rig pumps thru cement equipment. Break circulation @ 2 bpm w/ pickoff issues to 1050 psi. Bled down and re-attempt while working pipe. No other pickoff issues. Circulate 2 bpm/620 psi, 4 bpm / 900 psi. CBU w/ 1200u max gas @ btms up. Sym Ops - PJSM w/ HES cmtrs. 180k up, 100k dn. MPD hold 250 PSI backpressure while circulating. Turnover to HES. Perform cement job as follows: Wet lines w/ FW. P/T 1000/4900 psi (test good). 30 bbls 10 ppg spacer 3 bpm/800 psi. 27 bbls 14 ppg cement 3 bpm/650 psi (1.517 yld / 90 sxs) Clear excess cmt from surface lines. Release dart from cement head (witness by co rep). HES displaced 10 bbls FW 4 bpm/600 psi. Turnover to Rig (MP #2) - Displace with 9 ppg brine 4 bpm/694 psi until last 20 bbls. Slowed to 2 bpm/FCP 1110 psi. Rot/Recip pipe intil last 10 bbls (10 rpm, 6k tq). Work out tq and park string in tension for last 10 bbls. 175k up. Bumped plug @ 1514 stks / 1517 calc stks. CIP @ 10:35. Pressured up to 3500 psi w/ rig pumps and attempt to set hanger 3x while bleeding off MPD back psi to 150 to create higher differential psi for set (no go). 2.5 bbls total loss MPD maintain 240-260 PSI back pressure while pumping & 420 PSI static. Lineup on HES cementers. Psi up 4500 psi, indication of good set on liner hanger. S/O to blk wt. P/U to 225k to confirm positive set. S/O to blk wt. Bleed off psi & check floats (floats good). Bled back 2 bbls. Psi up to 5000 psi, release LRT. P/U expose dogs on running tool. Dog down zxp to engage element. New- 140k up, 103k dn R/U and test 7" and 4.5" liner to 2500 psi w/ 30 min hold. Chart and record same (test good). 2.5 bbls pumped / 2.5 bled back. BOL @ 14,109' MD / TOL @ 9998' MD. R/D and L/D cement equipment. L/D working single, 2x dp pups. B/D cmt line. B/O and L/D BOT cement head. Lineup thru TDS. Displace well from liner top from 9.2 LSND to 9 ppg brine. 30 bbl spacer. 6 bpm, 700 psi, 20 rpm, 2-4k tq. TOOH w/ 4" XT-39 14# drill pipe f/ 9998' t/ 4116' racking 62 stands in the derrick. Perform rig service & prepare rig floor for laying down drill pipe. TOOH laying down 129 total 4" drill pipe singles f/ 4116' t/ 42'. L/D Baker liner running tool - tool looked good and dog sub had sheared. Clear rig floor & break XOs and pup joint off cement head Halliburton e-line truck had 2 gallon glycol leak to pad . Notified security, pad operator and environmental. Halliburton repair heater hose on truck and refill coolant. Hallburton & Welltec spot trucks. PJSM with Doyon, Halliburton, Welltec & DSM. Mobilize equipment to the rig floor & load Welltec tractor into the pipe shed. R/U sheaves and lubricator. Install lubricator with 5' extension, close annular. M/U CLB/CCL assembly with Welltec tractor. Install pack-off. Daily (midnight) losses = 92 bbls, Cumulative losses = 546.8 bbls total H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 40 bbls Daily / 1,960 bbls Total. H2O from G&I Source Water: 140 bbls Daily / 140 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 974 bbls Daily / 6,060 bbls Total. Activity Date Ops Summary 10/31/2020 RIH w/ HES E-line w/ CCL, GR, CBL (RBT) with Welltech tractors from surface to tag depth of 14,024' (correlated off MWD logs). Tractor down F/ 10,100' ELM. POOH logging F/ 14,024' up to 12,900' ELM. Logs indicated TOC @ 13,590' ELM. Submit logs to engineer. POOH with E-line. B/O and L/D tractors. Redress tools and standby for orders.,Drain stack, remove wear bushing and install test plug. L/D 30' mousehole. C/O upper pipe rams to 2-3/8" solid body.,R/D & release wireline,R/U test equipment & mobilize test joints. PJSM. Attempt to fill stack - leaking. Remove, redress test plug & fill stack with water. Sim-ops: perform derrick inspection, service crown & R&R #1 conveyor paddles.,Test BOPs as per PTD & Hilcorp requirements. All tests performed w/ fresh water against a test plug for 5 min each, 250 PSI low, annular tested to 2500 PSI, all other tests to 4000 PSI. AOGCC inspector Bill Bixby waived witness of testing at 05:48 on 31 October. 1) Blind rams, choke valves 12, 13, 14, kill Demco & XT-39 dart valve. 2) Choke valves 9, 11, HCR kill, XT-39 FOSV & upper IBOP.,3) Choke valves 5, 8, 10, manual kill, 3.5" dart valve & lower IBOP. 4) Choke valves 4, 6, 6 & 3.5" FOSV. 5) Choke valve 2. 6) Super choke A - 1500 PSI. 7) Adj choke B - 1500 PSI. 8) Upper 2-3/8" rams on 2-3/8" test joint, choke valves 1 &3. 9) Annular on 2-3/8" test joint to 2500 PSI. 10) Manual choke valve. 11) Lower 2-7/8"x5" VBR on 4" test joint,12) Lower 2-7/8"x5" VBR on 3.5" test joint. Accumulator: 3025 PSI system pressure, 1600 PSI after closure, 200 PSI recovery in 38 sec, full recovery in 200 sec, 6 nitrogen bottle average 2165 PSI. Actual 9.5 hours of testing due to daylight savings time,Drain BOP stack, pull test plug & rig down test equipment. Blow down lines. Install 7-1/8" I.D. wear bushing and RILDS.,R/U power tongs, M/U XO to FOSV and mobilize Halliburton perforating gun handling tools to the rig floor. PJSM w/ Doyon rig crew, Doyon casing, Halliburton and DSM for running perf guns.,M/U 10 Halliburton 2-7/8" Maxforce 17.5 gram, 6 SPF, 60° phasing perforating guns, 38.6" penetration, 0.37" Entry Hole Diameter. 64' loaded, 5' blank, 55' loaded, 36' blank, 63' loaded. M/U perforating head (2 pin / 3200 PSI) w/ XO, 30.80' 2-3/8" joint, disconnect & 2-3/8" EUE x 2-3/8" H503 XO to 266.29'. H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 90 bbls Daily / 2,050 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 140 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 159 bbls Daily / 6,219 bbls Total. 11/1/2020 RIH w/ 2.88" TCPs F/ 230' - T/ 4,204' MD singling in with 2-3/8" H503, 4.7# drill pipe. Drift 1.70". 90 ft/min running speed. M/U tq 1800 ft/lbs. 55k up, 53k dn.,TIH w/ 2.88" TCPs & 2.375" work string on 4" drill pipe from the derrick f/ 4,204'. No weight observed at 4-1/2" liner top. Tag bottom on depth at 14,024' with 10K. Rack back stand to 13,967'. RIH w/ single to place bullnose at 13,995.71'. Install FOSV, 5' pup joint & M/U top drive. Fill lines. 145K PUW / 110K SO.,Drop 0.625" ball & allow to gravitate 20 mins. while conducting PJSM. Pump 2.6 BPM, 1200 PSI, ball on seat at 510 stks. Open choke HCR & close annular on 4" pipe. Pressure up & fire guns at 2930 PSI with good indication at surface. Pressure stabilized at 310 PSI on DP & choke. Bleed off pressure & observe no flow. Open annular.,Perf intervals: 13,773'-13,836', 13,872'-13,927', 13,932'-13996'. Total shots = 1032, 6 shots per foot, 60° phasing, 38.6" penetration, 0.37" effective hole diameter.,POOH racking back 3 stands f/ 13,995' t/ 13,714' with good hole fill. 145K PU / 110K SO. Circulate 2 bottoms up at 4.5 BPH, 2710 PSI. 334u max gas on first bottoms up. Gas level at 155u at 1.5 bottoms up. Stop pumps observe gas percolating. Continue circulating to 2 bottoms up, gas dropped to 33u. 9.0 ppg in and out. Flow check 30 min. Initial flow at 3 BPH slowed to 1.5 BPH and held steady.,Resume pumping 4.5 BPM, 2775 PSI and begin weighting up 0.2 ppg to 9.2 ppg. 303u max gas at bottoms up which dropped to 33u. Good 9.2 ppg in & out. Perform 10 min flow check - static. Obtain slow pump rates. Blow down the top drive, choke & kill lines.,POOH f/ 13,714' t/ 12,264' laying down 4" drill pipe. Utilizing trip tank with slight losses for first 15 stands laid down.,Daily losses = 0 bbls, Cumulative losses = 604.8 bbls Total. H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6- Mile: 0 bbls Daily / 2,050 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 140 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total Cuttings/mud/cement to MPU G&I: 57 bbls Daily / 6,276 bbls Total. 11/2/2020 POOH laying down 4" drill pipe f/ 12,264' t/ 4,236'. Pumped 15 bbl 10.2 ppg dry job at 12228'. RIH w/ 7 stands from the derrick f/ 4,236' t/ 4,836'. POOH laying down 4" drill pipe f/ 4,836' t/ 4,204'. 63K PU / 60K SO. Correct displacement.,Monitor well - static. R/U double stack power tongs, M/U FOSV w/ Hydril 503 XO. PJSM for laying down 2-3/8".,POOH laying down 2-3/8" Hydril 503 workstring f/ 4,204' t/ 265'. Correct displacement.,Monitor well - static. PJSM. L/D spent Halliburton perforating guns from 265'. All guns fired and in good condition. Clear rig floor. Correct displacement.,Pull wear bushing. R/U 2-3/8" casing equipment. Mobilize 3-1/2" hanger to the rig floor. Begin loading 3-1/2" tubing in the pipe shed. Well static.,M/U WLEG shear out sub and Baker 43A FH hydrostatic set SSR packer to 18'. RIH w/ 2-3/8" 4.7# L-80 EUE tubing f/ 18' t/ 3,753' @ 80'/min. Torque to 1300 ft/lbs with Doyon casing double stack tongs. Fill on the fly & top off every 15 joints. Back up jaws crimped joint #96, swap with joint #135. Load 330 joints of 3-1/2" tubing in the pipe shed.,R/D 2-3/8" equipment and R/U 3-1/2" equipment. Break 2-3/8" EUE XO off FOSV. Verify count of 3-1/2" tubing in the pipe shed. Well static.,M/U 2-3/8" EUE x 3-1/2" EUE XO and run 3-1/2" 9.3# L-80 EUE tubing f/ 3753' to 3973'. Torque to 3200 ft/lbs with Doyon casing double stack tongs. Fill on the fly & top off every 15 joints.,Daily losses = 0 bbls, Cumulative losses = 546.80 bbls Total. H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 70 bbls Daily / 2,120 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 140 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 6,276 bbls Total. Well Name: Field: County/State: MP L-21A Milne Point Hilcorp Energy Company Composite Report , Alaska 50-029-22629-01-00API #: 11/3/2020 POOH laying down 4" drill pipe f/ 12,264' t/ 4,236'. Pumped 15 bbl 10.2 ppg dry job at 12228'. RIH w/ 7 stands from the derrick f/ 4,236' t/ 4,836'. POOH laying down 4" drill pipe f/ 4,836' t/ 4,204'. 63K PU / 60K SO. Correct displacement.,Monitor well - static. R/U double stack power tongs, M/U FOSV w/ Hydril 503 XO. PJSM for laying down 2-3/8".,POOH laying down 2-3/8" Hydril 503 workstring f/ 4,204' t/ 265'. Correct displacement.,Monitor well - static. PJSM. L/D spent Halliburton perforating guns from 265'. All guns fired and in good condition. Clear rig floor. Correct displacement.,Pull wear bushing. R/U 2-3/8" casing equipment. Mobilize 3-1/2" hanger to the rig floor. Begin loading 3-1/2" tubing in the pipe shed. Well static.,M/U WLEG shear out sub and Baker 43A FH hydrostatic set SSR packer to 18'. RIH w/ 2-3/8" 4.7# L-80 EUE tubing f/ 18' t/ 3,753' @ 80'/min. Torque to 1300 ft/lbs with Doyon casing double stack tongs. Fill on the fly & top off every 15 joints. Back up jaws crimped joint #96, swap with joint #135. Load 330 joints of 3-1/2" tubing in the pipe shed.,R/D 2-3/8" equipment and R/U 3-1/2" equipment. Break 2-3/8" EUE XO off FOSV. Verify count of 3-1/2" tubing in the pipe shed. Well static.,M/U 2-3/8" EUE x 3-1/2" EUE XO and run 3-1/2" 9.3# L-80 EUE tubing f/ 3753' to 3973'. Torque to 3200 ft/lbs with Doyon casing double stack tongs. Fill on the fly & top off every 15 joints.,Daily losses = 0 bbls, Cumulative losses = 546.80 bbls Total. H2O from L-Pad: 0 bbls Daily / 1,850 bbls Total. H20 from 6-Mile: 70 bbls Daily / 2,120 bbls Total. H2O from G&I Source Water: 0 bbls Daily / 140 bbls Total. Recycle to ORT: 0 bbls Daily / 180 bbls Total. Cuttings/mud/cement to MPU G&I: 0 bbls Daily / 6,276 bbls Total. 11/4/2020 PJSM, LRS bullhead down IA 260 bbls 9.2 CI brine @ 1.8 bpm, ICP1800 psi / FCP 1995 psi. Freeze protect IA w/ 55 bbls diesel 1.6 bpm, 2200 FCP. Shut down w/ 1800 psi and slowly dropping. Lineup on tbg, pressure up to 4200 psi and hold 5 min setting BOT 4..5" completion packer. Bleed down tbg to 1500 psi. Lineup on IA and P/T to 2500 psi w/ 30 min hold (test good). AOGCC rep Bob Noble waived witness to MIT.,Lineup on tbg. LRS pressure up to 5017 psi attempting to shear WLEG shoe (no go). Bleed down and pressure up w/ rig test pump to 5400 psi (no go). Discuss with completion engineer (Ian Toomey). Pressure up to 5250 psi with good indication of shear on WLEG sub. Turnover to LRS and freeze protect tbg w/ 18 bbls diesel .8 bpm, 2200 psi. Rig off hi-line power at 09:00,Bleed down IA to zero. R/D LRS. Lubricate in BPV. Secure well and release from L-21A to F-62A. Rig released at 12:00,PJSM. R/D peripheral equipment. Demob rockwasher, 3rd party shacks. Skid floor into rig move position. RDMO of L-21A. Walk sub off well and around well row staged to exit pad.,Swap to F-62A report. Daily losses (injection) = 333 bbls, Cumulative losses = 890.30. 27 October, 2020 Milne Point M Pt L Pad MPU L-21A 500292262901 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Definitive Survey Report Well: Wellbore: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-21A Actual RKB @ 49.95usft Design:MPU L-21A Database:NORTH US + CANADA MD Reference:MPU L-21A Actual RKB @ 49.95usft North Reference: Well MPL-21 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPL-21, MPL-21 usft usft 0.00 0.00 6,031,876.390 544,806.190 16.70Wellhead Elevation:usft0.00 70° 29' 52.643 N 149° 38' 0.902 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU L-21A Model NameMagnetics IFR 10/17/2020 15.84 80.90 57,361.00000000 Phase:Version: Audit Notes: Design MPU L-21A 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:10,166.97 17.890.000.0033.25 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 10/27/2020 Survey Date 3_Gyro-CT_Drill pipe H037Gb: Continuous on wire in dril pipe108.75 7,058.75 MPL-21 Gyrodata NSG in 5" DP (MPL-21 12/15/1995 3_MWD A001Mb/ISC4: BGGM declination correction on7,137.59 10,166.97 MPL-21 MWD - Prod HS (MPL-21)12/08/1995 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa10,175.00 14,086.23 MPU L-21A MWD+IFR2+MS+Sag (1) (M 10/26/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 33.25 0.00 0.00 33.25 0.00 0.00-16.70 6,031,876.39 544,806.19 0.00 0.00 UNDEFINED 108.75 0.10 147.72 108.75 -0.06 0.0458.80 6,031,876.33 544,806.23 0.13 -0.04 3_Gyro-CT_Drill pipe (1) 208.75 0.14 123.54 208.75 -0.20 0.18158.80 6,031,876.19 544,806.37 0.06 -0.13 3_Gyro-CT_Drill pipe (1) 308.75 0.17 210.15 308.75 -0.39 0.21258.80 6,031,876.00 544,806.40 0.21 -0.31 3_Gyro-CT_Drill pipe (1) 408.75 0.44 96.32 408.75 -0.56 0.52358.80 6,031,875.83 544,806.71 0.53 -0.38 3_Gyro-CT_Drill pipe (1) 508.75 0.92 79.16 508.74 -0.45 1.69458.79 6,031,875.95 544,807.88 0.52 0.09 3_Gyro-CT_Drill pipe (1) 608.75 1.59 80.22 608.72 -0.07 3.84558.77 6,031,876.35 544,810.03 0.67 1.12 3_Gyro-CT_Drill pipe (1) 708.75 2.71 75.74 708.64 0.75 7.50658.69 6,031,877.19 544,813.69 1.13 3.02 3_Gyro-CT_Drill pipe (1) 808.75 3.30 71.97 808.51 2.22 12.53758.56 6,031,878.69 544,818.71 0.62 5.96 3_Gyro-CT_Drill pipe (1) 908.75 5.58 76.44 908.20 4.25 19.99858.25 6,031,880.76 544,826.16 2.30 10.19 3_Gyro-CT_Drill pipe (1) 1,008.75 7.95 80.65 1,007.50 6.52 31.55957.55 6,031,883.10 544,837.69 2.42 15.89 3_Gyro-CT_Drill pipe (1) 1,108.75 10.89 84.00 1,106.14 8.63 47.771,056.19 6,031,885.31 544,853.90 2.99 22.89 3_Gyro-CT_Drill pipe (1) 10/27/2020 6:52:54PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Definitive Survey Report Well: Wellbore: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-21A Actual RKB @ 49.95usft Design:MPU L-21A Database:NORTH US + CANADA MD Reference:MPU L-21A Actual RKB @ 49.95usft North Reference: Well MPL-21 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 1,208.75 11.83 84.74 1,204.18 10.56 67.371,154.23 6,031,887.35 544,873.49 0.95 30.74 3_Gyro-CT_Drill pipe (1) 1,308.75 13.14 77.53 1,301.82 13.95 88.681,251.87 6,031,890.87 544,894.77 2.03 40.52 3_Gyro-CT_Drill pipe (1) 1,408.75 16.47 64.83 1,398.51 22.44 112.621,348.56 6,031,899.51 544,918.66 4.63 55.95 3_Gyro-CT_Drill pipe (1) 1,508.75 17.21 58.85 1,494.23 36.12 138.111,444.28 6,031,913.34 544,944.07 1.88 76.80 3_Gyro-CT_Drill pipe (1) 1,608.75 17.56 55.44 1,589.66 52.33 163.201,539.71 6,031,929.70 544,969.05 1.08 99.93 3_Gyro-CT_Drill pipe (1) 1,708.75 19.11 50.41 1,684.59 71.32 188.241,634.64 6,031,948.84 544,993.98 2.21 125.70 3_Gyro-CT_Drill pipe (1) 1,808.75 20.77 44.65 1,778.60 94.37 213.321,728.65 6,031,972.04 545,018.91 2.57 155.34 3_Gyro-CT_Drill pipe (1) 1,908.75 22.54 40.40 1,871.54 121.59 238.201,821.59 6,031,999.40 545,043.63 2.36 188.88 3_Gyro-CT_Drill pipe (1) 1,958.75 24.64 37.23 1,917.37 137.19 250.721,867.42 6,032,015.07 545,056.06 4.91 207.57 3_Gyro-CT_Drill pipe (1) 2,008.75 26.50 35.10 1,962.47 154.61 263.441,912.52 6,032,032.57 545,068.67 4.15 228.06 3_Gyro-CT_Drill pipe (1) 2,108.75 28.78 32.71 2,051.05 193.13 289.282,001.10 6,032,071.24 545,094.28 2.53 272.65 3_Gyro-CT_Drill pipe (1) 2,208.75 31.95 29.99 2,137.33 236.31 315.532,087.38 6,032,114.58 545,120.26 3.45 321.81 3_Gyro-CT_Drill pipe (1) 2,308.75 33.77 29.59 2,221.32 283.40 342.482,171.37 6,032,161.82 545,146.92 1.83 374.90 3_Gyro-CT_Drill pipe (1) 2,408.75 33.72 28.86 2,304.48 331.88 369.602,254.53 6,032,210.46 545,173.75 0.41 429.37 3_Gyro-CT_Drill pipe (1) 2,508.75 33.36 28.19 2,387.83 380.42 395.992,337.88 6,032,259.15 545,199.84 0.52 483.67 3_Gyro-CT_Drill pipe (1) 2,608.75 32.88 28.78 2,471.58 428.45 422.042,421.63 6,032,307.33 545,225.60 0.58 537.38 3_Gyro-CT_Drill pipe (1) 2,708.75 33.97 27.38 2,555.04 477.05 447.962,505.09 6,032,356.08 545,251.22 1.34 591.59 3_Gyro-CT_Drill pipe (1) 2,808.75 33.91 27.51 2,638.00 526.60 473.692,588.05 6,032,405.78 545,276.65 0.09 646.65 3_Gyro-CT_Drill pipe (1) 2,908.75 33.45 27.96 2,721.22 575.68 499.502,671.27 6,032,455.02 545,302.16 0.52 701.28 3_Gyro-CT_Drill pipe (1) 3,008.75 33.30 28.67 2,804.73 624.11 525.592,754.78 6,032,503.60 545,327.96 0.42 755.39 3_Gyro-CT_Drill pipe (1) 3,058.75 33.91 28.50 2,846.37 648.41 538.832,796.42 6,032,527.97 545,341.05 1.23 782.58 3_Gyro-CT_Drill pipe (1) 3,108.75 35.27 28.19 2,887.53 673.39 552.312,837.58 6,032,553.03 545,354.37 2.74 810.49 3_Gyro-CT_Drill pipe (1) 3,158.75 36.14 27.69 2,928.13 699.17 565.982,878.18 6,032,578.89 545,367.89 1.84 839.23 3_Gyro-CT_Drill pipe (1) 3,208.75 37.17 27.56 2,968.24 725.62 579.822,918.29 6,032,605.42 545,381.57 2.07 868.65 3_Gyro-CT_Drill pipe (1) 3,258.75 37.12 26.93 3,008.10 752.46 593.642,958.15 6,032,632.34 545,395.23 0.77 898.43 3_Gyro-CT_Drill pipe (1) 3,308.75 36.86 27.42 3,048.04 779.22 607.382,998.09 6,032,659.18 545,408.80 0.79 928.12 3_Gyro-CT_Drill pipe (1) 3,358.75 38.55 26.77 3,087.59 806.45 621.303,037.64 6,032,686.49 545,422.56 3.47 958.31 3_Gyro-CT_Drill pipe (1) 3,408.75 40.16 26.99 3,126.25 834.73 635.643,076.30 6,032,714.85 545,436.72 3.23 989.62 3_Gyro-CT_Drill pipe (1) 3,458.75 41.80 27.51 3,164.00 863.87 650.653,114.05 6,032,744.09 545,451.56 3.35 1,021.98 3_Gyro-CT_Drill pipe (1) 3,508.75 43.12 27.96 3,200.89 893.75 666.363,150.94 6,032,774.05 545,467.09 2.71 1,055.23 3_Gyro-CT_Drill pipe (1) 3,558.75 44.41 27.54 3,236.99 924.36 682.473,187.04 6,032,804.75 545,483.00 2.64 1,089.31 3_Gyro-CT_Drill pipe (1) 3,608.75 45.17 27.11 3,272.48 955.65 698.633,222.53 6,032,836.14 545,498.98 1.64 1,124.05 3_Gyro-CT_Drill pipe (1) 3,658.75 46.39 26.04 3,307.35 987.70 714.663,257.40 6,032,868.28 545,514.82 2.88 1,159.48 3_Gyro-CT_Drill pipe (1) 3,708.75 47.20 25.50 3,341.58 1,020.52 730.513,291.63 6,032,901.19 545,530.46 1.80 1,195.58 3_Gyro-CT_Drill pipe (1) 3,758.75 48.91 24.46 3,375.00 1,054.23 746.213,325.05 6,032,935.00 545,545.95 3.75 1,232.48 3_Gyro-CT_Drill pipe (1) 3,808.75 50.74 24.00 3,407.26 1,089.07 761.883,357.31 6,032,969.92 545,561.42 3.73 1,270.45 3_Gyro-CT_Drill pipe (1) 3,858.75 52.09 24.22 3,438.44 1,124.74 777.853,388.49 6,033,005.69 545,577.17 2.72 1,309.30 3_Gyro-CT_Drill pipe (1) 3,908.75 52.96 23.79 3,468.86 1,160.99 793.993,418.91 6,033,042.03 545,593.09 1.87 1,348.76 3_Gyro-CT_Drill pipe (1) 3,958.75 53.52 24.40 3,498.78 1,197.56 810.343,448.83 6,033,078.69 545,609.22 1.49 1,388.58 3_Gyro-CT_Drill pipe (1) 4,008.75 54.26 24.76 3,528.25 1,234.29 827.153,478.30 6,033,115.52 545,625.80 1.59 1,428.70 3_Gyro-CT_Drill pipe (1) 10/27/2020 6:52:54PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Definitive Survey Report Well: Wellbore: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-21A Actual RKB @ 49.95usft Design:MPU L-21A Database:NORTH US + CANADA MD Reference:MPU L-21A Actual RKB @ 49.95usft North Reference: Well MPL-21 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,058.75 55.10 25.27 3,557.16 1,271.26 844.403,507.21 6,033,152.59 545,642.83 1.87 1,469.18 3_Gyro-CT_Drill pipe (1) 4,108.75 56.48 24.73 3,585.27 1,308.73 861.873,535.32 6,033,190.17 545,660.07 2.90 1,510.21 3_Gyro-CT_Drill pipe (1) 4,158.75 57.79 24.69 3,612.40 1,346.88 879.433,562.45 6,033,228.42 545,677.40 2.62 1,551.91 3_Gyro-CT_Drill pipe (1) 4,208.75 58.85 24.84 3,638.66 1,385.52 897.253,588.71 6,033,267.16 545,694.98 2.14 1,594.15 3_Gyro-CT_Drill pipe (1) 4,258.75 59.44 23.28 3,664.30 1,424.71 914.753,614.35 6,033,306.45 545,712.24 2.93 1,636.82 3_Gyro-CT_Drill pipe (1) 4,308.75 60.75 22.56 3,689.23 1,464.63 931.623,639.28 6,033,346.47 545,728.88 2.90 1,680.00 3_Gyro-CT_Drill pipe (1) 4,358.75 61.72 22.31 3,713.29 1,505.15 948.353,663.34 6,033,387.08 545,745.36 1.99 1,723.69 3_Gyro-CT_Drill pipe (1) 4,408.75 63.34 22.28 3,736.35 1,546.19 965.183,686.40 6,033,428.22 545,761.94 3.24 1,767.92 3_Gyro-CT_Drill pipe (1) 4,458.75 64.19 22.44 3,758.46 1,587.67 982.243,708.51 6,033,469.79 545,778.75 1.72 1,812.63 3_Gyro-CT_Drill pipe (1) 4,508.75 65.42 21.63 3,779.74 1,629.61 999.213,729.79 6,033,511.83 545,795.47 2.86 1,857.75 3_Gyro-CT_Drill pipe (1) 4,558.75 66.21 21.28 3,800.23 1,672.06 1,015.903,750.28 6,033,554.38 545,811.89 1.70 1,903.28 3_Gyro-CT_Drill pipe (1) 4,608.75 68.03 20.96 3,819.66 1,715.03 1,032.493,769.71 6,033,597.44 545,828.23 3.69 1,949.27 3_Gyro-CT_Drill pipe (1) 4,708.75 71.03 19.56 3,854.63 1,802.91 1,064.923,804.68 6,033,685.51 545,860.12 3.27 2,042.86 3_Gyro-CT_Drill pipe (1) 4,808.75 70.21 19.89 3,887.82 1,891.70 1,096.763,837.87 6,033,774.49 545,891.42 0.88 2,137.15 3_Gyro-CT_Drill pipe (1) 4,908.75 71.72 20.10 3,920.43 1,980.53 1,129.083,870.48 6,033,863.50 545,923.20 1.52 2,231.61 3_Gyro-CT_Drill pipe (1) 5,008.75 69.54 20.15 3,953.60 2,069.11 1,161.543,903.65 6,033,952.26 545,955.12 2.18 2,325.87 3_Gyro-CT_Drill pipe (1) 5,108.75 71.09 20.20 3,987.28 2,157.49 1,194.013,937.33 6,034,040.82 545,987.06 1.55 2,419.95 3_Gyro-CT_Drill pipe (1) 5,208.75 72.04 20.10 4,018.90 2,246.55 1,226.693,968.95 6,034,130.07 546,019.20 0.95 2,514.74 3_Gyro-CT_Drill pipe (1) 5,308.75 71.39 20.38 4,050.28 2,335.63 1,259.544,000.33 6,034,219.35 546,051.50 0.70 2,609.61 3_Gyro-CT_Drill pipe (1) 5,408.75 71.42 19.97 4,082.16 2,424.60 1,292.234,032.21 6,034,308.50 546,083.65 0.39 2,704.32 3_Gyro-CT_Drill pipe (1) 5,508.75 71.96 19.35 4,113.58 2,514.00 1,324.174,063.63 6,034,398.08 546,115.05 0.80 2,799.21 3_Gyro-CT_Drill pipe (1) 5,608.75 72.20 19.26 4,144.35 2,603.80 1,355.624,094.40 6,034,488.06 546,145.96 0.25 2,894.33 3_Gyro-CT_Drill pipe (1) 5,708.75 72.90 18.59 4,174.34 2,694.04 1,386.564,124.39 6,034,578.47 546,176.35 0.95 2,989.71 3_Gyro-CT_Drill pipe (1) 5,808.75 72.70 18.36 4,203.91 2,784.64 1,416.834,153.96 6,034,669.25 546,206.07 0.30 3,085.23 3_Gyro-CT_Drill pipe (1) 5,908.75 71.70 18.41 4,234.48 2,875.00 1,446.864,184.53 6,034,759.77 546,235.56 1.00 3,180.44 3_Gyro-CT_Drill pipe (1) 6,008.75 71.69 18.25 4,265.88 2,965.12 1,476.724,215.93 6,034,850.07 546,264.87 0.15 3,275.38 3_Gyro-CT_Drill pipe (1) 6,108.75 71.95 18.56 4,297.08 3,055.27 1,506.724,247.13 6,034,940.38 546,294.32 0.39 3,370.38 3_Gyro-CT_Drill pipe (1) 6,208.75 71.29 18.21 4,328.62 3,145.32 1,536.654,278.67 6,035,030.61 546,323.70 0.74 3,465.28 3_Gyro-CT_Drill pipe (1) 6,308.75 71.83 18.65 4,360.25 3,235.32 1,566.644,310.30 6,035,120.78 546,353.15 0.68 3,560.14 3_Gyro-CT_Drill pipe (1) 6,408.75 71.03 18.87 4,392.09 3,325.08 1,597.134,342.14 6,035,210.71 546,383.09 0.83 3,654.92 3_Gyro-CT_Drill pipe (1) 6,508.75 72.29 19.37 4,423.56 3,414.76 1,628.224,373.61 6,035,300.57 546,413.64 1.35 3,749.82 3_Gyro-CT_Drill pipe (1) 6,608.75 71.23 18.64 4,454.86 3,504.55 1,659.154,404.91 6,035,390.54 546,444.02 1.27 3,844.77 3_Gyro-CT_Drill pipe (1) 6,708.75 72.92 17.79 4,485.63 3,594.93 1,688.884,435.68 6,035,481.08 546,473.21 1.87 3,939.91 3_Gyro-CT_Drill pipe (1) 6,808.75 71.85 18.11 4,515.90 3,685.60 1,718.264,465.95 6,035,571.92 546,502.03 1.11 4,035.22 3_Gyro-CT_Drill pipe (1) 6,908.75 71.21 16.39 4,547.58 3,776.18 1,746.384,497.63 6,035,662.66 546,529.61 1.75 4,130.06 3_Gyro-CT_Drill pipe (1) 7,008.75 72.14 18.29 4,579.02 3,866.78 1,774.684,529.07 6,035,753.42 546,557.36 2.03 4,224.98 3_Gyro-CT_Drill pipe (1) 7,058.75 71.55 18.64 4,594.60 3,911.85 1,789.734,544.65 6,035,798.57 546,572.13 1.35 4,272.48 3_Gyro-CT_Drill pipe (1) 7,137.59 72.30 18.50 4,619.06 3,982.89 1,813.604,569.11 6,035,869.76 546,595.57 0.97 4,347.43 3_MWD (2) 7,201.32 72.06 19.03 4,638.57 4,040.34 1,833.114,588.62 6,035,927.31 546,614.74 0.88 4,408.09 3_MWD (2) 7,400.90 71.52 15.47 4,700.95 4,221.36 1,889.334,651.00 6,036,108.65 546,669.86 1.72 4,597.63 3_MWD (2) 10/27/2020 6:52:54PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Definitive Survey Report Well: Wellbore: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-21A Actual RKB @ 49.95usft Design:MPU L-21A Database:NORTH US + CANADA MD Reference:MPU L-21A Actual RKB @ 49.95usft North Reference: Well MPL-21 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 7,495.17 70.82 18.03 4,731.38 4,306.79 1,915.044,681.43 6,036,194.23 546,695.05 2.68 4,686.83 3_MWD (2) 7,591.78 70.26 20.65 4,763.57 4,392.73 1,945.204,713.62 6,036,280.34 546,724.68 2.62 4,777.88 3_MWD (2) 7,686.16 71.85 21.72 4,794.21 4,475.96 1,977.464,744.26 6,036,363.75 546,756.44 2.00 4,866.99 3_MWD (2) 7,778.34 71.46 20.75 4,823.23 4,557.52 2,009.154,773.28 6,036,445.49 546,787.64 1.08 4,954.34 3_MWD (2) 7,869.97 71.37 19.83 4,852.43 4,638.98 2,039.274,802.48 6,036,527.12 546,817.26 0.96 5,041.11 3_MWD (2) 7,967.41 70.91 16.73 4,883.94 4,726.52 2,068.194,833.99 6,036,614.83 546,845.65 3.05 5,133.30 3_MWD (2) 8,062.29 70.72 19.08 4,915.12 4,811.78 2,095.734,865.17 6,036,700.25 546,872.68 2.35 5,222.91 3_MWD (2) 8,156.78 70.53 20.31 4,946.47 4,895.70 2,125.774,896.52 6,036,784.34 546,902.21 1.24 5,312.00 3_MWD (2) 8,251.57 71.21 19.57 4,977.53 4,979.89 2,156.314,927.58 6,036,868.70 546,932.24 1.03 5,401.50 3_MWD (2) 8,347.40 71.52 19.84 5,008.15 5,065.38 2,186.934,958.20 6,036,954.36 546,962.34 0.42 5,492.26 3_MWD (2) 8,442.97 71.21 20.38 5,038.69 5,150.42 2,218.074,988.74 6,037,039.58 546,992.96 0.63 5,582.75 3_MWD (2) 8,535.21 72.01 22.15 5,067.79 5,231.98 2,249.825,017.84 6,037,121.33 547,024.21 2.02 5,670.12 3_MWD (2) 8,629.99 71.53 22.03 5,097.44 5,315.40 2,283.675,047.49 6,037,204.93 547,057.55 0.52 5,759.90 3_MWD (2) 8,725.66 71.22 24.27 5,128.00 5,398.75 2,319.315,078.05 6,037,288.49 547,092.69 2.24 5,850.17 3_MWD (2) 8,817.62 70.63 24.39 5,158.05 5,477.94 2,355.115,108.10 6,037,367.89 547,128.01 0.65 5,936.53 3_MWD (2) 8,913.50 71.38 24.46 5,189.26 5,560.49 2,392.605,139.31 6,037,450.65 547,165.00 0.79 6,026.60 3_MWD (2) 9,008.36 70.92 23.47 5,219.91 5,642.52 2,429.065,169.96 6,037,532.90 547,200.96 1.10 6,115.87 3_MWD (2) 9,102.17 71.96 23.58 5,249.77 5,724.06 2,464.565,199.82 6,037,614.64 547,235.96 1.11 6,204.37 3_MWD (2) 9,197.47 71.57 23.47 5,279.59 5,807.05 2,500.695,229.64 6,037,697.84 547,271.59 0.42 6,294.45 3_MWD (2) 9,292.41 71.81 20.73 5,309.42 5,890.55 2,534.595,259.47 6,037,781.53 547,304.98 2.75 6,384.33 3_MWD (2) 9,387.55 71.18 20.29 5,339.62 5,975.05 2,566.215,289.67 6,037,866.22 547,336.08 0.79 6,474.45 3_MWD (2) 9,483.60 72.15 20.83 5,369.83 6,060.41 2,598.235,319.88 6,037,951.76 547,367.58 1.14 6,565.53 3_MWD (2) 9,599.04 71.44 20.76 5,405.90 6,162.93 2,637.165,355.95 6,038,054.50 547,405.89 0.62 6,675.05 3_MWD (2) 9,694.15 70.85 19.59 5,436.64 6,247.41 2,668.205,386.69 6,038,139.16 547,436.42 1.32 6,764.98 3_MWD (2) 9,789.30 71.60 20.93 5,467.26 6,331.92 2,699.405,417.31 6,038,223.85 547,467.11 1.55 6,854.98 3_MWD (2) 9,884.30 71.25 19.96 5,497.52 6,416.30 2,730.855,447.57 6,038,308.41 547,498.05 1.04 6,944.94 3_MWD (2) 9,978.49 70.39 20.71 5,528.47 6,499.72 2,761.775,478.52 6,038,392.00 547,528.46 1.18 7,033.82 3_MWD (2) 10,072.54 71.24 19.92 5,559.38 6,583.02 2,792.605,509.43 6,038,475.48 547,558.79 1.20 7,122.57 3_MWD (2) 10,166.97 72.30 20.20 5,588.92 6,667.26 2,823.375,538.97 6,038,559.90 547,589.04 1.16 7,212.19 3_MWD (2) 10,175.00 72.26 20.11 5,591.36 6,674.44 2,826.005,541.41 6,038,567.10 547,591.63 1.18 7,219.84 3_MWD+IFR2+MS+Sag (3) 10,241.20 65.62 21.63 5,615.14 6,732.14 2,847.985,565.19 6,038,624.92 547,613.26 10.26 7,281.50 3_MWD+IFR2+MS+Sag (3) 10,289.19 65.32 22.60 5,635.06 6,772.59 2,864.425,585.11 6,038,665.46 547,629.45 1.94 7,325.03 3_MWD+IFR2+MS+Sag (3) 10,324.52 65.82 22.98 5,649.67 6,802.24 2,876.885,599.72 6,038,695.19 547,641.73 1.72 7,357.08 3_MWD+IFR2+MS+Sag (3) 10,421.17 66.92 13.54 5,688.49 6,886.21 2,904.555,638.54 6,038,779.31 547,668.89 9.02 7,445.49 3_MWD+IFR2+MS+Sag (3) 10,515.48 66.79 10.77 5,725.56 6,970.98 2,922.815,675.61 6,038,864.18 547,686.64 2.70 7,531.77 3_MWD+IFR2+MS+Sag (3) 10,610.40 66.99 11.63 5,762.82 7,056.62 2,939.775,712.87 6,038,949.91 547,703.08 0.86 7,618.48 3_MWD+IFR2+MS+Sag (3) 10,704.97 69.06 8.34 5,798.21 7,142.97 2,954.955,748.26 6,039,036.34 547,717.74 3.90 7,705.32 3_MWD+IFR2+MS+Sag (3) 10,801.10 72.21 5.82 5,830.09 7,232.95 2,966.115,780.14 6,039,126.38 547,728.35 4.11 7,794.38 3_MWD+IFR2+MS+Sag (3) 10,895.87 76.56 4.60 5,855.59 7,323.82 2,974.385,805.64 6,039,217.29 547,736.08 4.75 7,883.40 3_MWD+IFR2+MS+Sag (3) 10,990.28 78.51 5.24 5,875.97 7,415.66 2,982.295,826.02 6,039,309.17 547,743.43 2.17 7,973.23 3_MWD+IFR2+MS+Sag (3) 10/27/2020 6:52:54PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Definitive Survey Report Well: Wellbore: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-21A Actual RKB @ 49.95usft Design:MPU L-21A Database:NORTH US + CANADA MD Reference:MPU L-21A Actual RKB @ 49.95usft North Reference: Well MPL-21 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 11,085.12 79.39 5.94 5,894.15 7,508.30 2,991.365,844.20 6,039,401.85 547,751.94 1.18 8,064.17 3_MWD+IFR2+MS+Sag (3) 11,180.07 79.44 5.82 5,911.59 7,601.15 3,000.925,861.64 6,039,494.74 547,760.94 0.13 8,155.46 3_MWD+IFR2+MS+Sag (3) 11,275.09 79.13 6.59 5,929.26 7,693.96 3,011.015,879.31 6,039,587.61 547,770.47 0.86 8,246.89 3_MWD+IFR2+MS+Sag (3) 11,371.27 79.13 6.73 5,947.39 7,787.78 3,021.965,897.44 6,039,681.48 547,780.86 0.14 8,339.54 3_MWD+IFR2+MS+Sag (3) 11,464.55 78.87 6.53 5,965.19 7,878.73 3,032.545,915.24 6,039,772.49 547,790.88 0.35 8,429.34 3_MWD+IFR2+MS+Sag (3) 11,560.31 79.13 6.30 5,983.46 7,972.14 3,043.045,933.51 6,039,865.95 547,800.82 0.36 8,521.46 3_MWD+IFR2+MS+Sag (3) 11,655.55 78.87 5.23 6,001.64 8,065.16 3,052.435,951.69 6,039,959.01 547,809.65 1.14 8,612.87 3_MWD+IFR2+MS+Sag (3) 11,749.88 79.32 3.88 6,019.48 8,157.49 3,059.795,969.53 6,040,051.38 547,816.45 1.48 8,702.99 3_MWD+IFR2+MS+Sag (3) 11,844.27 79.51 4.05 6,036.82 8,250.05 3,066.205,986.87 6,040,143.97 547,822.31 0.27 8,793.05 3_MWD+IFR2+MS+Sag (3) 11,939.31 77.86 4.32 6,055.47 8,342.99 3,073.006,005.52 6,040,236.94 547,828.55 1.76 8,883.59 3_MWD+IFR2+MS+Sag (3) 12,034.13 78.19 4.51 6,075.14 8,435.47 3,080.146,025.19 6,040,329.45 547,835.13 0.40 8,973.79 3_MWD+IFR2+MS+Sag (3) 12,128.81 77.93 5.13 6,094.73 8,527.78 3,087.926,044.78 6,040,421.79 547,842.35 0.70 9,064.02 3_MWD+IFR2+MS+Sag (3) 12,223.67 78.12 5.68 6,114.41 8,620.16 3,096.676,064.46 6,040,514.22 547,850.54 0.60 9,154.62 3_MWD+IFR2+MS+Sag (3) 12,318.35 75.27 5.93 6,136.20 8,711.82 3,105.986,086.25 6,040,605.92 547,859.30 3.02 9,244.71 3_MWD+IFR2+MS+Sag (3) 12,413.63 70.28 7.02 6,164.41 8,802.21 3,116.236,114.46 6,040,696.37 547,869.00 5.35 9,333.88 3_MWD+IFR2+MS+Sag (3) 12,508.26 66.15 6.63 6,199.52 8,889.44 3,126.686,149.57 6,040,783.65 547,878.92 4.38 9,420.10 3_MWD+IFR2+MS+Sag (3) 12,603.00 61.89 4.83 6,241.01 8,974.16 3,135.206,191.06 6,040,868.41 547,886.93 4.81 9,503.34 3_MWD+IFR2+MS+Sag (3) 12,697.71 58.19 3.87 6,288.30 9,055.96 3,141.446,238.35 6,040,950.24 547,892.67 4.00 9,583.10 3_MWD+IFR2+MS+Sag (3) 12,790.94 55.01 2.00 6,339.62 9,133.67 3,145.446,289.67 6,041,027.96 547,896.21 3.80 9,658.29 3_MWD+IFR2+MS+Sag (3) 12,887.35 51.65 3.05 6,397.19 9,210.92 3,148.836,347.24 6,041,105.22 547,899.14 3.59 9,732.84 3_MWD+IFR2+MS+Sag (3) 12,982.94 47.09 4.16 6,459.42 9,283.30 3,153.376,409.47 6,041,177.62 547,903.24 4.85 9,803.12 3_MWD+IFR2+MS+Sag (3) 13,077.89 42.16 4.97 6,526.98 9,349.77 3,158.666,477.03 6,041,244.11 547,908.12 5.23 9,867.99 3_MWD+IFR2+MS+Sag (3) 13,172.06 38.06 5.21 6,598.99 9,410.18 3,164.036,549.04 6,041,304.55 547,913.13 4.36 9,927.14 3_MWD+IFR2+MS+Sag (3) 13,266.74 34.04 4.10 6,675.52 9,465.70 3,168.586,625.57 6,041,360.09 547,917.34 4.30 9,981.37 3_MWD+IFR2+MS+Sag (3) 13,361.38 33.18 3.09 6,754.34 9,517.98 3,171.876,704.39 6,041,412.39 547,920.32 1.08 10,032.14 3_MWD+IFR2+MS+Sag (3) 13,456.46 33.06 2.97 6,833.97 9,569.86 3,174.616,784.02 6,041,464.28 547,922.75 0.14 10,082.35 3_MWD+IFR2+MS+Sag (3) 13,551.59 29.69 0.50 6,915.18 9,619.35 3,176.176,865.23 6,041,513.77 547,924.00 3.79 10,129.92 3_MWD+IFR2+MS+Sag (3) 13,646.61 30.38 1.55 6,997.44 9,666.90 3,177.026,947.49 6,041,561.32 547,924.57 0.91 10,175.44 3_MWD+IFR2+MS+Sag (3) 13,739.88 30.20 1.27 7,077.98 9,713.93 3,178.187,028.03 6,041,608.35 547,925.45 0.25 10,220.55 3_MWD+IFR2+MS+Sag (3) 13,835.89 29.55 2.43 7,161.23 9,761.73 3,179.727,111.28 6,041,656.15 547,926.70 0.91 10,266.51 3_MWD+IFR2+MS+Sag (3) 13,930.75 29.88 4.93 7,243.62 9,808.64 3,182.747,193.67 6,041,703.08 547,929.44 1.35 10,312.08 3_MWD+IFR2+MS+Sag (3) 14,026.40 29.81 3.49 7,326.59 9,856.11 3,186.247,276.64 6,041,750.56 547,932.65 0.75 10,358.33 3_MWD+IFR2+MS+Sag (3) 14,086.23 29.51 2.63 7,378.58 9,885.67 3,187.827,328.63 6,041,780.13 547,934.05 0.87 10,386.95 3_MWD+IFR2+MS+Sag (3) 14,109.00 29.51 2.63 7,398.39 9,896.88 3,188.337,348.44 6,041,791.34 547,934.50 0.00 10,397.77 PROJECTED to TD Approved By:Checked By:Date: 10/27/2020 6:52:54PM COMPASS 5000.15 Build 91E Page 6 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.10.27 15:56:32 -08'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.10.29 11:32:42 -08'00' TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 1 1 1 1 1 97 1 1 1 1 1 X Yes No X Yes No 90 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?:X 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:X Yes No Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface? Yes X No Spacer returns? Yes X 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:Yes No Casing Rotated? Yes No Reciprocated? Yes No % Returns during job Cement returns to surface? Yes No Spacer returns? 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: Premium G 90 1.52 10,022.98 Threaded Coupler 5 TSH W521 Baker 1.57 10,022.98 10,021.41 10,033.76 10,032.43 Liner hanger 6 TSH W521 Baker 9.45 10,032.43 3.85 10,037.61 10,033.76 XO 5 TSH W521 Baker 1.33 Liner Pup Joint 4 1/2 12.6 L-80 TXP-BTC SR Tenaris 14,024.80 Liner Joint 4 1/2 12.6 L-80 TXP-BTC SR Tenaris 3,987.19 14,024.80 10,037.61 14,066.17 14,025.90 Landing Collar 5 BTC Baker 1.10 14,025.90 1.52 14,067.69 14,066.17 Liner Joint 5 12.6 L-80 TXP-BTC SR Tenaris 40.27 Float Collar 5 BTC Baker XO Liner Joint 4 1/2 12.6 L-80 TXP-BTC SR Tenaris 39.16 14,106.85 14,067.69 Baker HRD-E HD ZXP www.wellez.net WellEz Information Management LLC ver_04818br 3108.34Fresh Water 3 Ftg. Returned Ftg. Cut Jt. Ftg. Balance No. Jts. Delivered 108 No. Jts. Run 100 8 Length Measurements W/O Threads Ftg. Delivered Ftg. Run RKB to CHF Type of Shoe:Baker Round Nose Floa Casing Crew:Doyon Closure OKTypeStage Collar @ Bump press 14,109.0014,109.00 CEMENTING REPORT Csg Wt. On Slips:35,000 LSND 10:35 10/30/2020 13,590 14 27 Bump press Radial Bond Log Bump Plug? / 152.91/153.22 3500 0 RigFIRST STAGE10Tuned Spacer 30 94 99 1110 Bump Plug? Csg Wt. On Hook:160 Type Float Collar:Baker No. Hrs to Run:37 6 Baker BTC Baker 2.15 14,109.00 14,106.85 22.50 10,021.41 9,998.91 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP L-21A Date Run 28-Oct-20 CASING RECORD County State Alaska Supv.C. Montague / C. Demoski 14,066.00 Floats Held 15.19 27 027 2500 Brine Rotate Csg Recip Csg Ft. Min. PPG9.2 Shoe @ 14109 FC @ Top of Liner 9999 SECOND STAGE15.57 25.3 162 Casing (Or Liner) Detail und Nose Float Sh HD ZXP liner top 5 13,590 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/19/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU L-21A (PTD 220-062) Radial Bond Tool 10/31/2020 Please include current contact information if different from above. Received by the AOGCC 11/19/2020 PTD: 2200620 E-Set:34290 Abby Bell 11/23/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 11/05/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-21A (PTD 220-062) FINAL Halliburton LWD 10/20/2020 to 10/27/2020 Final Definitive Directional Survey MD/TVD 10/20/2020 •ABG At-Bit Gamma •PCG Pressure Cased Gamma Ray •ADR Azimuthal Deep resistivity •ALD Azimuthal Lithodensity •CTN Compensated Thermal Neutron Data Folders: Received by the AOGCC 11/05/2020 PTD: 2200620 E-Set: 34193 Abby Bell 11/05/2020 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: MILNE PT UNIT L -21A Contractor/Rig No.: Doyon 14 - Operator: Hilcorp North Slope, LLC Type Operation: DRILL Sundry No: Type Test: INIT PTD#: 2200620 DATE: 10/18/2020 - Inspector Bob Noble Operator Rep: Vanderpool Rig Rep: Carlo Reviewed By: loj P.I. Supry J Comm Insp Source Inspector Test Pressures: Inspection No: bopRCN201019155724 Rams: Annular: Valves: MASP: 250/4000 250/4000 - 250/4000 ' 1420 ' Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: CHOKE MANIFOLD: P/F P/F Visual Alarm Time/Pressure P/F Location Gen.: -P Trip Tank P P System Pressure 3100 P Housekeeping: P Pit Level Indicators P P Pressure After Closure 1675 - P PTD On Location P Flow Indicator P P 200 PSI Attained 38 P Standing Order Posted _P Meth Gas Detector P P Full Pressure Attained 191 P - Well Sign -P H2S Gas Detector P P Blind Switch Covers: All Stations P - Drl. Rig P MS Misc NA _ _NA Nitgn. Bottles (avg): 6-2142 _ - P - Hazard Sec. P #4 Rams 0 none NA_ ACC Misc NA Misc NA #5 Rams _ 0 none NA INSIDE REEL VALVES: FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly -- 1 P • Stripper 0 none NA No. Valves 14 FP ✓ Lower Kelly _ 1 -P ' Annular Preventer 1 - 13 5/8" P - Manual Chokes 1 P Ball Type - 2 P-. #1 Rams 1 2 7/8"_x 5" V - P Hydraulic Chokes 1 P Inside BOP 2 P #2 Rams 1 - Blinds - P- CH Mise 0 NA FSV Misc 0 NA #3 Rams 1 2 7/8" x 5" V' P - #4 Rams 0 none NA_ #5 Rams _ 0 none NA INSIDE REEL VALVES: #6 Rams 0 none NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3 1/8" P Quantity P/F HCR Valves 2- 3 1/8" P Inside Reel Valves 0 NA Kill Line Valves 2 3 1/8" P Check Valve 0 none NA BOP Misc 0 none NA Number of Failures: 1 'z Test Results Test Time 10.5 Remarks: CMV #3 failed and had to be rebuilt. Bag was tested against 3 1/2" tj, VBRs were tested against 3 1/2" and 4 1/2" tj. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Injection Completion 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,060'N/A Casing Collapse Conductor N/A Surface 3,090 Production 5,410 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: 10/25/2020 N/A N/A and N/A Authorized Title: Operations Manager Authorized Name: Chad Helgeson 80' 7,218' 14,135' Perforation Depth MD (ft): N/A 14,135' Perforation Depth TVD (ft): Tubing Size: 7,611'7" 5,750 112' 4,652' 112' 7,249' 20" 9-5/8" MILNE POINT, KUPARUK RIVER OIL MILNE PT UNIT L-21A PRESENT WELL CONDITION SUMMARY N/A TVD Burst N/A 7,240 MD N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025509 & ADL0355017 220-060 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 C.O. 432D 50-029-22629-01-00 Hilcorp Alaska, LLC COMMISSION USE ONLY Tubing Grade: Tubing MD (ft): N/A and N/A N/A and N/A 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Ian Toomey itoomey@hilcorp.com 777-8520 7,355' 14,060' 7,355' 1,420 N/A Length Size Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:22 am, Oct 08, 2020 320-426 Chad A Helgeson 2020.10.07 17:19:34 -08'00' 220-062 DLB DLB 10/08/2020 X 10-407 MGR09OCT20 DSR-10/12/2020 BOPE test to 4000 psi. Annular to 2500 psi. MIT-IA to 2500 psi for 30 minute witnessed test. 24 hour notice. Comm. 10/12/2020 dts 10/12/2020 JLC 10/12/2020 RBDMS HEW 11/12/2020 Injection Completion Well: MPU L-21A Date: 10/05/2020 Well Name: MPU L-21A API Number: 50-029-22629-01-00 Current Status: Plugged for RD Pad: L-Pad Estimated Start Date: October 25th, 2020 Rig: Doyon 14 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 220-062 First Call Engineer: Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) Second Call Engineer: David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number: Job Type: Injection completion Most recent SBHP: Not perforated Maximum Expected BHP: 2,143 psi @ 7,229’ TVD EMW = 5.71 ppg MPSP: 1,420 psi Gas Column Gradient = 0.1 psi/ft Max Inclination: 70° - 73° from 4,650’ to 12,400’ MD Max Dogleg: 4.9°/100ft at 1,955’ MD Tree: Cameron 3-1/8” 5M BPV Profile: 3” CIW Type H Brief Well Summary: MPU L-21 is currently plugged back awaiting Doyon 14 to sidetrack the well to the new L-21A bottom hole location in the Kuparuk sand. Procedural Note: This work will be performed by Doyon 14 as a continuation of the drilling of L-21A. These steps will replace Section 17 of the approved PTD #220-062. Objective: x Run CBL. x Perforate the Kuparuk sands. x Run 3-1/2” x 2-3/8” injection completion. 17.0 Completion: 17.1 Change LPR to 2-3/8” solid body rams and PT to 250/4,000 psi with 2-3/8” test joint. 17.2 PT the 4-1/2” liner, liner top packer and 7” casing to 3,500 psi for 30 minutes (charted). 17.3 RU 2-3/8” handling equipment. Ensure appropriate well control crossovers are on the rig floor. 17.4 PU and MU CBL/GR/CCL assembly and RIH on 2-3/8”, 4.7#, L-80, Hydril 503 work string to ~4,000’. xx Need enough 2-3/8” work string to get from the LTP to PBTD. x Torque: Min = 1,500 ft-lbs; Optimal = 1,800 ft-lbs; Max = 2,600 ft-lbs 17.5 MU 4” x 2-3/8” crossover. Change handling equipment to 4” DP. 17.6 Continue to TIH with CBL assembly on 4” DP, use caution when entering the liner top, to just above shoe track. Lightly tag PBTD. 17.7 POOH logging per Halliburton (correlate log to MWD log) to determine TOC. Correct PTD # DLB CBL data to AOGCC for review and agreement for TOC. Injection Completion Well: MPU L-21A Date: 10/05/2020 17.8 Once the TOC has been determined, TOOH with 4” DP to the 2-3/8” work string. 17.9 Change handling equipment to 2-3/8”. 17.10 POOH laying down 2-3/8” work string and CBL assembly. 17.11 PU and MU 2-7/8”, 6 SPF, MaxForce, HMX TCP gun assembly per HES representative xx Gun length and blanks sections (if needed) will be determined by the Geologist after drilling the reservoir. Estimated Kuparuk sands from 13,762’ to 14,000’ (238’). 17.12 RIH TCP gun assembly on 2-3/8” work string to ~4,000’. 17.13 MU 4” x 2-3/8” crossover. Change handling equipment to 4” DP. 17.14 Continue to TIH with TCP gun assembly, use caution when entering the liner top, to just above shoe track. Lightly tag PBTD. 17.15 PU and space out to place the guns on depth. 17.16 Close the annular or UPR. Drop activation ball and allow the ball to gravitate to seat. Pressure up on the DP to 2,500 psi or as per HES to fire the guns. 17.17 Check for pressure under the annular or UPR and bleed to 0 psi if needed. Open the annular or UPR and observe the well for flow. 17.18 PU to above the top perforation to ensure the guns are free. Circulate bottoms up. Ensure the well is static or on a slight vac. 17.19 TOOH with 4” DP to the 2-3/8” work string. 17.20 POOH laying down 2-3/8” work string and TCP gun assembly. Verify that all shots have fired. 17.21 PU and MU the following packer assembly and RIH on 2-3/8”, 4.6#, L-80, IBT tubing to ±3,700’ filling the tubing on the fly topping off as needed. x WELG with solid shear out plug x 10’ pup joint, 2-3/8”, 4.6#, L-80, EUE 8rd tubing x Retrievable Packer, Baker FH, 4-1/2” x 2-3/8” EUE 8rd x 10’ pup joint, 2-3/8”, 4.6#, L-80, EUE 8rd tubing x Crossover, 2-3/8” 6.4#, L-80, IBT Box X EUE Pin x XX joints, 2-3/8”, 4.6#, L-80, IBT tubing x Crossover, 3-1/2”, 9.3#, EUE 8rd Box X 2-3/8”, 4.6#, IBT Pin 17.22 Change handling equipment to 3-1/2” tubing. 17.23 Continue to RIH with 2-3/8” injection packer on 3-1/2”, 9.3#, L-80, EUE 8rd to ±13,700’ filling the tubing on the fly topping off as needed. 17.24 PU and MU the tubing hanger with landing joint. 17.25 Land the tubing hanger and RILDS. Lay down the landing joint. Install the TWC. 17.26 ND the BOPE. NU the tubing head adapter and tree. 17.27 PT the tubing hanger void to 250/5,000 psi. PT the tree to 500/5,000 psi. Pull the TWC. Assure AOGCC in agreement with top of perforations. Injection Completion Well: MPU L-21A Date: 10/05/2020 17.28 RU to pump down the IA. Bullhead 247 bbls of corrosion inhibited brine followed by 55 bbls of diesel (max pump rate = 3 BPM). 17.29 RU to pump down the tubing and ensure the tubing is full. Pressure up on the tubing 4,100 psi and hold for 5 minutes to set the packer. 17.30 Bleed the tubing pressure to 1,500 psi. PT the IA to 2,500 psi for 30 minutes (charted). xx Notify the AOGCC 24 hours in advance to witness the PT. 17.31 Slow pressure up on the tubing to shear the solid shear out plug (estimated shear value: minimum = 4,585 psi: nominal = 4,827 psi; maximum = 5,068 psi). Bleed the IA to 0 psi. 17.32 Bullhead 18 bbls of diesel down the tubing. 17.33 Install BPV. RDMO Doyon 14. 17.34 Turn the well over to operations via handover form. No post rig work is required. Attachments: 1. Proposed schematic 2. Blank MOC Form _____________________________________________________________________________________ Revised By: TDF 9/24/2020 PROPOSED Milne Point Unit Well: MPU L-21A Last Completed: Future PTD: 220-062 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20"Conductor 91.1 /H-40 / N/A N/A Surface ±112’ 9-5/8"Surface 40 / L-80 /BTC 8.835 Surface ±7,249’ 7"Intermediate 26 / L-80 / BTC 6.276 Surface ±10,500’ 4-1/2”Liner 12.6 / L-80 /TXP 3.958 ±10,050’±14,060’ TUBING DETAIL 3-1/2” Tubing 6.6 / L-80 / EUE 8rd 2.992 Surface ±10,000’ 2-3/8”Tubing 6.4 / L-80 / EUE 8rd 1.995 ±10,000’±13,700’ JEWELRY DETAIL No Depth Item 1 TBD 7” x 4-1/2” Liner Top Packer 2 TBD Production Packer 3 TBD WLEG –Bottom @ TBD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Perforation Summary: OPEN HOLE / CEMENT DETAIL 24" 12-1/4" 8-1/2” 6-1/8” WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 77 deg Hole Angle through perforations = TREE & WELLHEAD Tree 3-1/8”–5M AlloyTree ‘FL’ Wellhead FMC 11” x 11” 5M,Gen 5 w/ 11” x 3.5”FMC Tubing Hanger, w/ NSCT Threads Top and bottom and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22629-01-00 Completed: TBD TD =14,4 060’00 (MD) / TD = 7,355’(TVD) 20”00 Ori g.DF Elev.: 50.4’/ GL Elev.: 16.7’ Nabors 22E 7”77 2 3 9-5/8”88 1 2 PBTD =BB 13,980’ (MD) / PBTD = 7,00 287’(TVD)77 Howco ES Cementer @ 2,132’ 4-1/2” WINDOW DETAIL Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: October 7, 2020 Subject: Changes to Approved Sundry Procedure for Well MPU L-21A Sundry #: ____-____ Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU L-21A Hilcorp Alaska, LLC Permit to Drill Number: 220-062 Surface Location: 1593' FNL, 209' FWL, Sec. 08, T13N, R10E, UM, AK Bottomhole Location: 2279' FNL, 1849' FEL, Sec. 32, T14N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to redrill the above referenced service 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 September, 2020. JMPi 2 1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 14060' TVD: 7355' 4a. Location of Well (Governmental Section):7. Property Designation: Surface: Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date: Total Depth:9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 15. Distance to Nearest Well Open Surface: x-544806 y- 6031876 Zone-4 to Same Pool: 1632' 16. Deviated wells: Kickoff depth: feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 6-1/8" 4-1/2" 12.6# L-80 TXP 4010' 10050' 5550' 14060' 7355' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): None TVD 112' 4652' 7611' 13558 - 13768 7139 - 7305 Hydraulic Fracture planned?Yes No 20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:50-029-Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Sr Pet Eng Sr Pet Geo Sr Res Eng September 20, 2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Nathan Sperry nathan.sperry@hilcorp.com 18. Casing Program:Top - Setting Depth - BottomSpecifications 2143 MPU L-21A Milne Point Field Kuparuk Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 1593' FNL, 209' FWL, Sec. 08, T13N, R10E, UM, AK ADL025509 & 355017 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1420 2509' FNL, 1858' FEL, Sec. 32, T14N, R10E, UM, AK 2279' FNL, 1849' FEL, Sec. 32, T14N, R10E, UM, AK 88-002 7013 6650' Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Effect. Depth TVD (ft): 14051' Effect. Depth MD (ft): 14155'7628' LengthCasing None Total Depth MD (ft):Total Depth TVD (ft): Surface Conductor/Structural 20"80' 7218' Authorized Signature: 250 sx Class 'G'Production Liner Intermediate 14135'7" 7539' 1396 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 250 sx Arctic Set I (Approx.)112' 7249' 14135' 9-5/8" See cover letter for other requirements.01-00 Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Commission Use Only Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): 131.2 ft3 Class 'G' s N ype o L l R b S Cass os N s No s N o D s s s D 84 o esp G S S 20 SS S s No s No S G y E S s No s Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 8.17.2020 By Samantha Carlisle at 8:49 am, Aug 18, 2020 Digitally 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: 2020.08.17 20:08:15 -08'00' Monty M Myers DSR-8/18/2020 220-062 SFD 8/18/2020 77 SFD 8/18/2020 SFD 8/18/2020 50-029-22629-01-00 50.4 10,500 BOPE test to 4000 psi. Annular test to 2500 psi. Completion sundry to follow. 16.7 SFD 8/31/2020 MGR02SEP2020GR02SEP2020 9/2/2020 9/2/2020 Area of Review MPL-21APTDAPI WELL STATUSTop of Kup C (MD)Top of Kup C (TVD)CBL Top of Cement (MD)CBL Top of Cement (TVD)Kuparuk C statusZonal Isolation195-191 50-029-22629-00-00 MPU L-21Kuparuk A, B & C WINJ13558' 7139' 12000' 6175' Cased/CementedHilcorp will P&A this well to complete MPU L-21A RedactedM. Guhl 2/9/2021 Milne Point Unit (MPU) L-21A Drilling Program Version 1 July 21, 2020 Table of Contents 1.0 Well Summary ................................................................................................................................. 2 2.0 Management of Change Information ............................................................................................ 3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Casing Inspection ............................................................................................................................ 4 6.0 Internal Reporting Requirements ................................................................................................. 5 7.0 Wellbore Schematics ....................................................................................................................... 6 8.0 Drilling / Completion Summary .................................................................................................... 7 9.0 Mandatory Regulatory Compliance / Notifications ..................................................................... 8 10.0 R/U and Test BOPE ...................................................................................................................... 10 11.0 Pull 3-1/2” Tubing ......................................................................................................................... 12 12.0 Mill 6-1/8” Window and Kick Off ............................................................................................... 13 13.0 Production Hole Section Summary ............................................................................................. 16 14.0 Drill 6-1/8” Production Hole Section ........................................................................................... 17 15.0 Run 4-1/2” Liner ........................................................................................................................... 20 16.0 Cement 4-1/2” Production Liner ................................................................................................. 23 17.0 Run 3-1/2” Kill String ................................................................................................................... 25 18.0 Doyon 14 BOP Schematic ............................................................................................................. 26 19.0 Wellhead Schematic ...................................................................................................................... 27 20.0 Days Vs Depth ............................................................................................................................... 28 21.0 Formation Tops & Information ................................................................................................... 29 22.0 Anticipated Drilling Hazards ....................................................................................................... 31 23.0 Doyon 14 Layout ........................................................................................................................... 33 24.0 FIT Procedure ............................................................................................................................... 34 25.0 Doyon 14 Choke Manifold Schematic ......................................................................................... 35 26.0 Casing Design Information .......................................................................................................... 36 27.0 6-1/8” Hole Section MASP ........................................................................................................... 37 28.0 Spider Plot (NAD 27) (Governmental Sections) ......................................................................... 38 29.0 Surface Plat (As Built) (NAD 27) ................................................................................................. 39 30.0 Drill Pipe Information .................................................................................................................. 40 Page 2 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 1.0 Well Summary Well MPU L-21A Pad Milne Point “L” Pad Planned Completion Type 4-1/2” Cemented Liner Target Reservoir(s) Kuparuk A Wellplan 8 Planned Well TD, MD / TVD 14,060’ MD / 7,355’ TVD PBTD, MD / TVD ±13,980 MD / 7,287’ TVD Surface Location (Governmental) 1593' FNL, 209' FWL, Sec 8, T13N, R10E, UM, AK Surface Location (NAD 27 – Zone 4) X=544,806.19 Y=6,031,876.39 Top of Productive Horizon (Governmental) 2509' FNL, 1858' FEL, Sec 32, T14N, R10E, UM, AK TPH Location (NAD 27) X=547,926.7, Y=6,041,538.4 BHL (Governmental) 2279' FNL, 1849' FEL, Sec 32, T14N, R10E, UM, AK BHL (NAD 27) X=547,933.3, Y=6,041,767.9 Drilling Days 11 Days Completion Days 2 Days Maximum Anticipated Pressure (Surface) 1,420 psi Maximum Anticipated Pressure (Downhole/Reservoir) 2,143 psi (5.7ppg EMW) Work String 4” 14# S-135 XT-39 / HT38 KB Elevation above MSL: 33.7 ft + 16.7 ft = 50.4 ft GL Elevation above MSL: 16.7 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 2.0 Management of Change Information Page 4 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 3.0 Tubular Program: Hole Section OD (in) ID (in) Drift (in) Conn OD (in) Wt (#/ft) Grade Conn Burst (psi) Collapse (psi) Tension (k-lbs) 6-1/8” 4-1/2” 3.968 3.833 45.00 12.6 L-80 TXP 8430 7500 288 4.0 Drill Pipe Information: Hole Section OD (in) ID (in) TJ ID (in) TJ OD (in) Wt (#/ft) Grade Conn M/U (Min) M/U (Max) Tension* (k-lbs) Production 4” 3.34” 2.5625” 4.875” 14 S-135 XT39 18,500 22,200 403 4” 3.34 2.5625 4.875 14 S-135 HT38 12,200 17,700 403 *Tension Rating Based on Premium Pipe 5.0 Casing Inspection All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 6.0 Internal Reporting Requirements 6.1 Fill out daily drilling report and cost report on Wellez. x Report covers operations from 6am to 6am x Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area – this will not save the data entered, and will navigate to another data entry tab. x Ensure time entry adds up to 24 hours total. x Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. x Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 6.2 Afternoon Updates x Submit a short operations update each work day to mmyers@hilcorp.com, pmazzolini@hilcorp.com , nathan.sperry@hilcorp.com, jengel@hilcorp.com joseph.lastufka@hilcorp.com and cdinger@hilcorp.com 6.3 Intranet Home Page Morning Update x Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 6.4 EHS Incident Reporting x Health and safety: Notify EHS field coordinator. x Environmental: Drilling Environmental coordinator x Notify Drlg Manager & Drlg Engineer x Submit Hilcorp Incident report to contacts above within 24 hrs 6.5 Casing Tally x Send final “As-Run” Casing tally to nathan.sperry@hilcorp.com, joseph.lastufka@hilcorp.com and cdinger@hilcorp.com 6.6 Casing and Cement report x Send casing and cement report for each string of casing to nathan.sperry@hilcorp.com joseph.lastufka@hilcorp.com and cdinger@hilcorp.com 6.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengel@hilcorp.com Drilling Engineer Nathan Sperry 907-777-8450 907.301.8996 nathan.sperry@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomey@hilcorp.com Geologist Radu Girbacea 907.777.8324 907.230.9490 rgirbacea@hilcorp.com Reservoir Engineer Daniel Taylor 907.777.8319 907.947.8051 dtaylor@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com Safety Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Drilling Tech Joe Lastufka 907.777.8400 907.227.8496 Joseph.Lastufka@hilcorp.com Page 6 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 7.0 Wellbore Schematics Page 7 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 8.0 Drilling / Completion Summary MPU L-21A is a sidetrack injection well targeting the Kuparuk River Pool, located on Milne Point ‘L-Pad’. The directional plan is a single string slant well with the kick off point at 10,200’ MD. Maximum hole angle is ~77 degrees. Drilling operations are expected to commence approximately September 20th, 2020, pending rig schedule. Production liner will be 4-1/2” 12.6# L-80 cemented liner run to 14,060’ MD / 7,355’ TVD. The well will be perforated post-rig. Doyon 14 will leave the well with the liner cemented and a kill string installed. A separate sundry will be submitted for P&A operations and completion operations on L-21A. There are no plans to pre-produce the well. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located on “B” pad. General sequence of operations: 1. MIRU Doyon 14 2. N/U 13-5/8” x 5M BOPE and test 3. Pull 3-1/2” tubing from cut 4. Set 7” WS and mill 6-1/8” window 5. Drill with kickoff (motor) assembly until sufficient separation achieved 6. Drill 6-1/8” hole with RSS to TD 7. Run and cement 4-1/2” production liner 8. Run 3-1/2” Kill String 9. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Production Hole: No mud logging. LWD: GR + Res Page 8 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 9.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. x BOP’s shall be tested at 1 week intervals prior to initiating window milling and 2 week intervals during the drilling and completion of MPU L-21A thereafter. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/4000 psi & subsequent tests of the BOP equipment will be to 250/4000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. x If the BOP is used to shut in on the well in a well control situation, notify AOGCC and test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid program and drilling fluid system”. x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements”. x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: x There are no variance requests at this time. Page 9 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 6-1/8” x 13-5/8” x 5M Hydril “GK” Annular BOP x 13-5/8” x 5M Hydril MPL Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Hydril MPL Single ram x 3-1/8” x 5M Choke Line x 3-1/8” x 5M Kill line x 3-1/8” x 5M Choke manifold x Standpipe, floor valves, etc Initial Test: 250/4000 Subsequent Tests: 250/4000 Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: x Well control event (BOPs utilized to shut in the well to control influx of formation fluids). x 24 hours notice prior to spud. x 24 hours notice prior to testing BOPs. x 24 hours notice prior to casing running & cement operations. x Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (O): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (O): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 10.0 R/U and Test BOPE 10.1 Reservoir abandonment was completed pre-rig via a separate Sundry. 10.2 Ensure Sundry, PTD, and drilling program are posted in the rig office and on the rig floor. 10.3 Ensure landing ring is installed on conductor. 10.4 Ensure (2) 4” threaded nipples are installed on opposite sides of the conductor with ball valves on each nipple. 10.5 Level pad and ensure enough room for layout of rig footprint and R/U. 10.6 Ensure rig mats cover entire footprint of rig. 10.7 MIRU Doyon 14, Ensure rig is centered over the wellhead to prevent any wear to BOPE or wellhead. 10.8 Mud loggers will not be used on L-21. 10.9 N/U 13-5/8” x 5M BOP as follows: x BOP configuration from top down: 13-5/8” x 5M annular / 13-5/8” x 5M double gate / 13- 5/8” x 5M mud cross / 13-5/8” x 5M single gate x Double gate ram should be dressed with 2-7/8” x 5” VBRs in top cavity, blind ram in bottom cavity. x Single ram can be dressed with 3-1/2” x 6” VBRs x N/U bell nipple, install flowline. x Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). x Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve 10.10 Run BOP test plug. 10.11 Test BOP to 250/4000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. x Test VBR’s with 3-1/2” and 4-1/2” test joints x Confirm test pressures with PTD x Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug x Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 10.12 R/D BOP test equipment. 10.13 Dump and clean mud pits, send spud mud to G&I pad for injection. 10.8 Install test dart in the BPV. N/D the tree/THA. 10.5 MIRU Doyon 14, Ensure rig is centered over the wellhead to prevent any wear to BOPE or wellhead. 10.7 Ensure the casing/cement envelope has been pressure tested pre-rig. If it has not, perform a pressure test to 2500 psi for 30 minutes (charted). Pull test dart and BPV. 10.3 Level pad and ensure enough room for layout of rig footprint and R/U. 10.6 Mud loggers will not be used on L-21. 10.4 Ensure rig mats cover entire footprint of rig. Page 11 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 10.14 Mix 9.0 ppg LSND fluid for production hole. 10.15 Set wearbushing in wellhead. 10.16 If needed, rack back as much 4” DP in derrick as possible to be used while drilling the hole section. 10.17 Ensure 6” liners in mud pumps. Page 12 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 11.0 Pull 3-1/2” Tubing 11.1 PU landing joint or spear and recover the tubing hanger. 11.2 Back out lock down screws. 11.3 Pull tubing hanger with landing joint/XO to the floor. 11.4 The tubing is expected to be in good condition. 11.5 Note and record PU weight required to pull the tubing from cut. 11.6 The expected weight of the string in a vertical hole filled with seawater is 83,500 lbs (assumes 10,300’ cut depth). 11.7 Circulate at least 1.5x BU after pulling the hanger to the floor. If desired, circulate a soap sweep surface-to-surface to clean the tubing. 11.8 Pull and lay down the tubing from the jet cut. 11.9 Run wear ring. 11.10 Contingency: PU 4” drill pipe and RIH with clean-out assembly and clean-out the well to the top of the tubing stub. The decision will be based on the tubing condition, how the tubing pulled, etc. If no cleanout run is needed, skip to section 12. 11.11 When on bottom circulate at max rate a minimum of 1X BU or until returns are clean. Pump high vis sweep if necessary. Displace to milling fluid. 11.12 POOH with clean-out assembly Page 13 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 12.0 Mill 6-1/8” Window and Kick Off Note: All following operations will be covered under by the PTD for L-21A 12.1 Whipstock Set Depth Information: x Planned TOW: ~10,200’ MD x WS will be set to avoid a collar based on the L-21 7” tally (Nabors 22E RKB of 28.7), Co Man, whipstock service hand, and drilling engineer to review parent tally and agree on the set depth x Deepest hydrocarbon bearing sand in 7” casing hole section is the Schrader Bluff OBD at 6,906’ MD, 4,545’ TVD 12.2 MU 6-1/8” mill/whipstock assembly as per WIS tally x Make up HWDP, storing magnets, and float sub x Ensure magnets are in trough, under shakers and flow area to capture metal shavings circulated 12.3 Install MWD and UBHO, and orient. Rack back mill assembly. x Ensure a dedicated MWD is available for orientation of the whipstock 12.4 Verify offset between MWD and whipstock tray, witnessed by Drilling Supervisor, MWD/DD and milling Rep. Document and record offset in well file 12.5 Slowly run in the hole as per fishing Rep. Run extremely slow through the BOP & wear bushing to prevent damaging the shear bolt. 12.6 Run in hole at 1 ½ to 2 minutes per stand. Ensure work string is stationary prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening the shear bolt and prematurely setting the anchor. 12.7 Shallow Test MWD 12.8 Stop at least 30-45’ above planned set depth (10,200’ MD), obtain survey with MWD. 12.9 Milling fluid will be 9.0 ppg LSND 12.10 With the bottom of the whipstock 30 – 45’ above the set depth, work torque out of string, measure and record P/U and S/O weights. Obtain good survey to orient whipstock face. 12.11 Orient whipstock to desired direction by turning DP in ¼ round increments. P/U and S/O on DP to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is 165q ROHS. Page 14 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 12.12 Whipstock Orientation Diagram: Desired orientation of the Whipstock face is 150R to 180R, target is 165 ROHS Hole Angle at window interval (10,200’ MD) is ~72°, Azimuth 20°. 12.13 Once whipstock is in desired orientation, set WS per fishing rep. 12.14 Pressure up per rep to set hydraulic set whipstock, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (35k shear value, verify after whipstock is picked up). 12.15 P/U 5-10’ above top of Whipstock. 12.16 CBU and confirm 9.0 ppg MW in/out x Ensure Mud properties are sufficient for transporting metal cuttings x Visc: 40-60, YP: 18-20 12.17 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window as per WIS Rep. Utilize 4 ditch magnets on the surface to catch metal cuttings. Pump high visc sweeps as necessary. 12.18 If possible, install catch trays in shaker underflow chute to help catch metal cuttings. 12.19 Clean catch trays and ditch magnets frequently while milling window 12.20 Mill window until the uppermost mill has passed across the entire tray. Dress and polish window as needed. 12.21 With upper mill at the end of the tray, this will drill ~ 20’ of new hole. 12.22 After window is milled and before POOH, shut down pumps and work milling assembly through window watching for drag. Dress and polish window as needed. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 180R 150R Page 15 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 12.23 Circulate Bottoms Up until even MW in/out and hole is clean of metal shavings. Reduce mud properties for drilling. 12.24 Pull back into 9-5/8” casing and perform FIT t/ 11.7 ppg EMW. Chart Test. 12.25 POOH & LD Milling BHA. Gauge Mills for wear. 12.26 If upper mill is under gauge, pick up second mill BHA with same assembly (to ensure same cut pattern) and perform dress off run to ensure window is correct diameter. 12.27 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris. Casing test and FIT digital data to AOGCC. Page 16 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 13.0 Production Hole Section Summary This is a single section 6-1/8” hole kicked off from uncemented pipe in the Colville and TD’d in the Kuparuk. The Kuparuk pore pressure is expected to be 5.7ppg EMW. Maintaining CBHP will be critical for maintaining HRZ and Kalubik stability. Note: Managed Pressure Drilling will be used in this hole section. Prior to drilling, verify all rig crew member are familiar with operation. If needed, install RCD bearing element and perform practice connections to familiarize crews with its operations. Managed Pressure Drilling will be used in this hole section. e 5.7ppg EMW. Page 17 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 14.0 Drill 6-1/8” Production Hole Section 14.1 PU 6-1/8” kickoff assembly. x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Workstring will be 4” 14# S-135 XT 39 x Run x2 Solid Plunger Floats for MPD 14.2 6-1/8” hole mud program summary: x Density: The Kuparuk reservoir pressure is expected to be 5.7ppg. 9.0ppg MW will be used. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. x Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. x Inhibition: 3% KCl will be used for inhibition. Watch MBT levels, dilute as necessary to maintain. Increase KCl % if needed x Run the centrifuge continuously while drilling the production hole, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. x PVT will be used throughout the drilling phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type: 9.0 - 10.5ppg 3% KCl Inhibited LSND WBM Properties: Section Density Viscosity Plastic Viscosity Yield Point Total Solids MBT pH 6-1/8” 9.0 -10.5 75-175 15-25 15-25 <10% < 7 8.5 – 9.0 14.3 TIH w/ 6-1/8” directional assembly on 4” DP to above window. Shallow test MWD and LWD on trip in. 14.4 Ensure even 9.0ppg MW in and out. Note: MPD is NOT needed for drilling with the motor assembly. 14.5 Drill 6-1/8” hole section with kickoff assembly at least until we have confirmed we have separation from the old wellbore. TOOH. Page 18 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 14.6 P/U 6-1/8” RSS Directional BHA x Ensure BHA components have been inspected previously. x Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. x Ensure TF offset is measured accurately and entered correctly into the MWD software. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. x Workstring will be 4” 14# S-135 XT 39 x Run x2 Solid Plunger Floats for MPD 14.7 Install MPD Element x Ensure rig crew is familiar with MPD connection operations x Ensure max pressure relief settings are set correction to ensure no wellbore damage is created 14.8 Drill 6-1/8” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 150-250 gpm (Target 200 ft/min AV) x RPM: 120 – for hole cleaning x WOB as needed x Target ECD and CBHP: 10.7 - 11.1 ppg EMW (11.1ppg max) x Utilize MPD to maintain CBHP (constant bottom hole pressure) on connections, following annular pressure ramp schedule x This will reduce the pumps on/ pumps off pressure cycles on shales x Slow ramp pumps on/off on each connection x Smooth connections are more important that connection time x Monitor connections for losses, adjust as necessary x Take MWD surveys every stand drilled. x Kuparuk PP estimate is 5.7 ppg. Good drilling and tripping practices are vital for avoidance of differential sticking and HRZ/Kalubik stability. x Watch for fluid losses while drilling through Kuparuk. 14.9 At TD, circulate a minimum of 2X BU x Circulate at full drill rate (150-250 gpm) while rotating at 120 rpm’s x Perform short trip to 7” window following the pressure schedule to maintain CBHP at the base of the HRZ. x We can slowly rack back a couple of stands while performing the BU circulations. x Attempt to pull through the Kalubik and HRZ on elevators to the window. Only initiate backreaming if necessary. x Circulate a minimum of 1.5X BU at the window prior to TIH on elevators. 14.10 At TD, circulate at least 1X BU. Observe well for flow, weight up to 10.2 ppg prior to TOOH 14.11 TOOH with the drilling assembly t/ 7” window while offsetting swab with MPD x Follow tripping schedule, matching string speed and annular pressure Page 19 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure x Rack back DP while TOOH, Do not lay down drill pipe. This is to minimize open hole time before liner is on bottom. 14.12 If backreaming is necessary: x Circulate at max rate while maintaining drilling ECD’s x Perform CBHP connections x Rotate at maximum rpm that can be sustained. x Limit pulling speed to 5 – 10 min/std (slip to slip time, not including connections). x If backreaming operations are commenced, continue backreaming to the window and circ at least a b/u once at the window. 14.13 CBU at 7” window 14.14 Continue TOOH to HWDP/ BHA, offsetting swab with MPD x Once inside casing, drop rabbit on remaining drillpipe on TOOH that will be used to run the 4.5” liner. Confirm diameter drift with Baker for setting liner hanger 14.15 Pull RCD Bearing element at HWDP 14.16 L/D 6-1/8” BHA 14.17 No additional logs are planned for the 6-1/8” hole section. Page 20 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 15.0 Run 4-1/2” Liner 15.1 Ensure rams have been tested on 4-1/2” test joint prior to running liner. 15.2 Ensure wear bushing is installed in wellhead. 15.3 R/U 4-1/2” casing running equipment. x Ensure 4-1/2” TXP crossover is on rig floor and M/U to FOSV. x Ensure all casing has been drifted prior to running. x Be sure to count the total # of joints before running. x Keep hole covered while R/U casing tools. x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info. 15.4 Run 4-1/2” liner per completion tally. x Dope pin end only w/ paint brush. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Run 1 centralizer per joint to the planned TOC 4-1/2” Tenaris TXP Make Up Torques Casing OD Minimum Optimum Maximum 4.5” 5,550 ft-lbs 6,170 ft-lbs 6,790 ft-lbs 4-1/2” Tenaris TXP Operating Limit Torques Casing OD Operating Yield 4.5” 6,790 ft-lbs 8,890 ft-lbs Page 21 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure Page 22 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 15.5 Ensure to run enough liner to provide for approx 150’ overlap inside 7” casing. Ensure hanger/pkr will not be set in a 7” connection. 15.6 Before picking up Baker ZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.7 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with “Pal mix”, ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.8 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 15.9 RIH w/ liner on DP no faster than 1-2 min / stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.10 Fill DP with top drive every 10 stands or as appropriate. 15.11 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every 5 stands. Record torque value if it becomes necessary to rotate the string to bottom. 15.12 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.13 RIH to TD as per running schedule. Monitor run for losses. Page 23 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 16.0 Cement 4-1/2” Production Liner 16.1 Circulate and condition mud for cement job x Break circulation slowly and stage up rate with reciprocation. Rotate DP slowly if hole condition allows, not exceed max torque or 20 rpms x Circulate minimum 3 liner annular volumes to condition hole and mud for cement job 16.2 Hold pre job safety meeting over upcoming liner cementing operations. Make room in pits for volume gained during cement job. Ensure adequate displacement volume is available. x Cement returns are not expected to surface, but may be seen after setting liner hanger and circulating, discuss how to hand returns if they are seen x Discuss pumps for displacement x Positions and expectations of all personnel involved in cement operations, have one hand in the pits specifically for strapping pits and recording volume returned. 16.3 4-1/2” Liner cement job will be a single stage. 16.4 RU cement head and cementing lines 16.5 Pump 5 bbls fresh water. Pressure test surface cement lines to 4000 psi. 16.6 Pump 60 bbls of 11.5 ppg spacer 16.7 Pump 14.0 ppg Class G Single Stage Slurry as per below calculations, 40% OH Excess: x Minimum TOC is 500’ above the Kuparuk. x Ensure cement slurry thickening time accounts for 30 min shutdown time for setting and releasing from liner hanger / packer. And compressive strength sufficient for perforation. Section: Calculation Vol (bbls) Vol (ft3) 6-1/8” OH x 4.5” Liner: (14,059’ – 13,115’) x .0168 bpf X 1.4 = 22.2 124.4 4.5” Shoe Track 80’ x 0.0152 bpf = 1.2 6.8 Total Volume 23.4 131.2 Cement Slurry System G Density 14.0 ppg Yield 1.52 ft3/sk Mixed Water 7.74 gal/sk 16.8 Drop liner wiper plug and displace with drilling mud. x Target max displacement rates to not exceed drilling ECDs x Slow pumps enough to check for liner wiper plug shear release 16.9 Continue displacing cement until liner wiper plug bumps, or displacement volume has been pumped. Page 24 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure x If plug does not bump, do not set the liner top packer, as string will be unsupported by an unset liner hanger. Discuss with Baker Rep. 16.10 Increase drill pipe pressure to set liner hanger, ~ 2700psi. Slack off to ensure liner hanger is set. 16.11 Increase pressure to release running tool from liner hanger. Pressure up in 500 psi increments holding for 5 min each up to 4000 psi until indication that running tool has released. 16.12 Pickup to expose rotating dog sub, set down on liner and set ZXP liner top packer. 16.13 Pressure up t/ 500 psi, pickup 2-3’ to verify that the HRD setting tool has released. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.14 Pick up above liner top. 16.15 CBU x 2, to clean up wellbore and check for any cement returns to surface or above liner top. 16.16 POOH, L/D 4” DP and inspect running tools. 16.17 L/D remaining 4” DP out of derrick. Ensure to report the following on wellez: x Pre flush type, volume (bbls) & weight (ppg) x Cement slurry type, lead or tail, volume & weight x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid x Note if casing is reciprocated or rotated during the job x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump pressure, do floats hold x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure x Note if pre flush or cement returns at surface & volume x Note time cement in place x Note calculated top of cement x Add any comments which would describe the success or problems during the cement job Send final “As-Run” casing tally & casing and cement report to nathan.sperry@hilcorp.com, itoomey@hilcorp.com, and cdinger@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 25 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 17.0 Run 3-1/2” Kill String 17.1 R/U and run 3-1/2” 9.2ppf L-80 EUE kill string to ~2,500’ MD (confirm depth with Ops Engineer) x Ensure appropriate well control crossovers on rig floor and ready. 17.2 Makeup the tubing hanger and landing joint. 17.3 Land hanger. RILDs and test hanger (500/5000 psi). 17.4 Freeze protect IA and Tubing. 17.5 Install BPV 17.6 ND BOPE 17.7 NU Tree & Pressure test to 5000 psi. 17.8 RDMO Doyon 14 A separate sundry will be submitted for completion operations. Page 26 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 18.0 Doyon 14 BOP Schematic Typical Ram Configuration Page 27 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 19.0 Wellhead Schematic FMC Gen 5 Typical 2-7/8” Page 28 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 20.0 Days Vs Depth Page 29 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 21.0 Formation Tops & Information Page 30 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure MPU L Pad Data Sheet Page 31 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 22.0 Anticipated Drilling Hazards Window Exit: Tracking Casing The KOP is uncemented. The lowside orientation and the motor run will give us the best opportunity to get kicked off successfully from the parent well. Production Hole Sections: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate with AV of 200 ft/min. Lost Circulation: Lost circulation has been seen in the Colville formation at EMW exceeding ~ 12.0 ppg. Monitor ECDs during production section to ensure ECDs stay below 12.0. Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. The Kuparuk FG is predicted to be ~11.2ppg. Ensure ECD’s remain below 11.2ppg after drilling into the Kuparuk. Wellbore Stability: This well will drill through historically trouble shales, HRZ & Kalubik. Maintain sufficient MW for stability and utilize MPD to maintain constant bottom hole pressure to mitigate on/off pressure cycles. Use MPD to offset swab effect while TOOH. Follow tripping in hole schedule to manage surge pressures on shales. Anti-Collision: This well has no close approaches on the planned wellpath. Monitor MWD survey for magnetic interference while drilling ahead. Faulting: There are no known faults in the hole section. H2S: Treat every hole section as though it has the potential for H2S. H2S events have typically been minor from L-pad Kuparuk wells. The vast majority of sample data is less than 10 ppm. L-32 recorded multiple samples with >100 ppm. L-35A had one sample test come back with 20 ppm. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. Page 32 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 33 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 23.0 Doyon 14 Layout Page 34 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 24.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 35 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 25.0 Doyon 14 Choke Manifold Schematic Page 36 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 26.0 Casing Design Information Page 37 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 27.0 6-1/8” Hole Section MASP Page 38 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 28.0 Spider Plot (NAD 27) (Governmental Sections) Page 39 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 29.0 Surface Plat (As Built) (NAD 27) Page 40 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 30.0 Drill Pipe Information 4” 14# S-135 XT-39 Page 41 Version 1 July 2020 Milne Point Unit L-21A Drilling Procedure 4” 14# S-135 HT-38 21 July, 2020 Plan: MPU L-21A WP06 Milne Point M Pt L Pad Plan: MPL-21 MPU L-21A Superceded by WP08 48005200560060006400680072007600True Vertical Depth (600 usft/in)6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000Vertical Section at 17.89° (600 usft/in)A8-I1950010000105001100011500120001250013000135001400014155MPL-217" TOW4 1/2" x 6 1/8"105001100011500120001250013000135001400014061MPU L-21A WP06KOP : Start Dir 12.3º/100' : 10500' MD, 5694.78'TVD : 60° RT TFEnd Dir : 10517' MD, 5700.15' TVDStart Dir 4º/100' : 10547' MD, 5709.37'TVDEnd Dir : 11014.51' MD, 5836.29' TVDStart Dir 4º/100' : 12252.95' MD, 6122.21'TVDEnd Dir : 13419.68' MD, 6800' TVDTotal Depth : 14060.78' MD, 7355.21' TVDHRZKLBKLGMKUP_DKUP_CKUP_B6KUP_A3KUP_A2KUP_A1KUP_A_BASEWELL DETAILS: Plan: MPL-21 NAD 1927 (NADCON CONUS) Alaska Zone 04Ground Level:16.70+N/-S +E/-WNorthingEastingLatittude Longitude0.00 0.006031876.39 544806.1970° 29' 52.643 N149° 38' 0.902 WCASING DETAILSTVD TVDSS MD Size Name5694.78 5644.38 10500.0077" TOW7355.21 7304.8114060.784-1/24 1/2" x 6 1/8"FORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation6803.40 6753.00 13423.60 HRZ6806.40 6756.00 13427.07 KLB6842.40 6792.00 13468.64 KLGM6970.40 6920.00 13616.44 KUP_D7097.40 7047.00 13763.09 KUP_C7104.40 7054.00 13771.17 KUP_B67205.40 7155.00 13887.79 KUP_A37220.40 7170.00 13905.11 KUP_A27245.40 7195.00 13933.98 KUP_A17302.40 7252.00 13999.80 KUP_A_BASEProject: Milne PointSite: M Pt L PadWell: Plan: MPL-21Wellbore: MPU L-21ADesign: MPU L-21A WP06SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 10500.00 71.05 20.69 5694.78 6964.43 2929.08 0.00 0.00 7527.47 KOP : Start Dir 12.3º/100' : 10500' MD, 5694.78'TVD : 60° RT TF210517.00 72.10 22.59 5700.15 6979.42 2935.03 12.30 60.00 7543.56 End Dir : 10517' MD, 5700.15' TVD310547.00 72.10 22.59 5709.37 7005.78 2945.99 0.00 0.00 7572.01 Start Dir 4º/100' : 10547' MD, 5709.37'TVD411014.51 76.65 3.74 5836.29 7442.00 3047.18 4.00 -78.62 8018.22 End Dir : 11014.51' MD, 5836.29' TVD512252.95 76.65 3.74 6122.21 8644.41 3125.82 0.00 0.00 9186.65 Start Dir 4º/100' : 12252.95' MD, 6122.21'TVD613419.68 30.00 2.00 6800.00 9553.11 3175.84 4.00 -178.8010066.79 End Dir : 13419.68' MD, 6800' TVD713760.78 30.00 2.00 7095.40 9723.56 3181.79 0.00 0.0010230.82 A8-I1814060.78 30.00 2.00 7355.21 9873.47 3187.02 0.00 0.0010375.09 Total Depth : 14060.78' MD, 7355.21' TVDSURVEY PROGRAMDate: 2020-07-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool109.20 7059.20 MPL-21 Gyrodata NSG in 5" DP (MPL-21) 3_Gyro-CT_Drill pipe7138.04 10500.00 MPL-21 MWD - Prod HS (MPL-21) 3_MWD10500.00 10900.00 MPU L-21A WP06 (MPU L-21A) 3_MWD_Interp Azi+Sag10900.00 14060.78 MPU L-21A WP06 (MPU L-21A) 3_MWD+IFR2+MS+SagSuperceded by WP08 6050 6325 6600 6875 7150 7425 7700 7975 8250 8525 8800 9075 9350 9625 9900 10175 10450 10725 South(-)/North(+) (550 usft/in)1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225 West(-)/East(+) (550 usft/in) A8-I1 5500 5750 6000 6250 6500 6750 7000 7250 7648 MPL-21 7" TOW 4 1/2" x 6 1/8" 6000 6250 6500 6750 7000 7250 7355 MPU L-21A WP06 KOP : Start Dir 12.3º/100' : 10500' MD, 5694.78'TVD : 60° RT TF End Dir : 10517' MD, 5700.15' TVD Start Dir 4º/100' : 10547' MD, 5709.37'TVD End Dir : 11014.51' MD, 5836.29' TVD Start Dir 4º/100' : 12252.95' MD, 6122.21'TVD End Dir : 13419.68' MD, 6800' TVD Total Depth : 14060.78' MD, 7355.21' TVD CASING DETAILS TVD TVDSS MD Size Name 5694.78 5644.38 10500.00 7 7" TOW 7355.21 7304.81 14060.78 4-1/2 4 1/2" x 6 1/8" Project: Milne Point Site: M Pt L Pad Well: Plan: MPL-21 Wellbore: MPU L-21A Plan: MPU L-21A WP06 WELL DETAILS: Plan: MPL-21 Ground Level: 16.70 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 6031876.39 544806.19 70° 29' 52.643 N 149° 38' 0.902 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPL-21, True North Vertical (TVD) Reference:MPU L-54 As-built RKB @ 50.40usft Measured Depth Reference:MPU L-54 As-built RKB @ 50.40usft Calculation Method:Minimum Curvature Superceded by WP08 Superceded by WP08 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-54 As-built RKB @ 50.40usft Design:MPU L-21A WP06 Database:NORTH US + CANADA MD Reference:MPU L-54 As-built RKB @ 50.40usft North Reference: Well Plan: MPL-21 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: M Pt L Pad, TR-13-10 usft Map usft usft °0.34Slot Radius:"0 6,029,799.28 544,529.55 0.00 70° 29' 32.230 N 149° 38' 9.412 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: MPL-21, MPL-21 usft usft 0.00 0.00 6,031,876.39 544,806.19 16.70Wellhead Elevation:usft0.00 70° 29' 52.643 N 149° 38' 0.902 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU L-21A Model NameMagnetics BGGM2020 9/21/2020 15.91 80.89 57,378.20199491 Phase:Version: Audit Notes: Design MPU L-21A WP06 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:10,500.00 17.890.000.0033.70 Inclination (°) Azimuth (°) +E/-W (usft) Tool Face (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections TVD System usft 0.000.000.000.002,929.086,964.435,694.7820.6971.0510,500.00 5,644.38 60.0011.196.2112.302,935.036,979.425,700.1522.5972.1010,517.00 5,649.75 0.000.000.000.002,945.997,005.785,709.3722.5972.1010,547.00 5,658.97 -78.62-4.030.974.003,047.187,442.005,836.293.7476.6511,014.51 5,785.89 0.000.000.000.003,125.828,644.416,122.213.7476.6512,252.95 6,071.81 -178.80-0.15-4.004.003,175.849,553.116,800.002.0030.0013,419.68 6,749.60 0.000.000.000.003,181.799,723.567,095.402.0030.0013,760.78 7,045.00 0.000.000.000.003,187.029,873.477,355.212.0030.0014,060.78 7,304.81 7/21/2020 5:44:46PM COMPASS 5000.15 Build 91E Page 2 Superceded by WP08 Superceded by WP08 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-54 As-built RKB @ 50.40usft Design:MPU L-21A WP06 Database:NORTH US + CANADA MD Reference:MPU L-54 As-built RKB @ 50.40usft North Reference: Well Plan: MPL-21 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS -16.70 Vert Section 33.70 0.00 33.70 0.00 0.000.00 544,806.196,031,876.39-16.70 0.00 0.00 109.20 0.10 109.20 -0.06 0.04147.72 544,806.236,031,876.3358.80 0.13 -0.04 209.20 0.14 209.20 -0.20 0.18123.54 544,806.376,031,876.19158.80 0.06 -0.13 309.20 0.17 309.20 -0.39 0.21210.15 544,806.406,031,876.00258.80 0.21 -0.31 409.20 0.44 409.20 -0.56 0.5296.32 544,806.716,031,875.83358.80 0.53 -0.38 509.20 0.92 509.19 -0.45 1.6979.16 544,807.886,031,875.95458.79 0.52 0.09 609.20 1.59 609.17 -0.07 3.8480.22 544,810.036,031,876.35558.77 0.67 1.12 709.20 2.71 709.09 0.75 7.5075.74 544,813.696,031,877.19658.69 1.13 3.02 809.20 3.30 808.96 2.22 12.5371.97 544,818.716,031,878.69758.56 0.62 5.96 909.20 5.58 908.65 4.25 19.9976.44 544,826.166,031,880.76858.25 2.30 10.19 1,009.20 7.95 1,007.95 6.52 31.5580.65 544,837.696,031,883.10957.55 2.42 15.89 1,109.20 10.89 1,106.59 8.63 47.7784.00 544,853.906,031,885.311,056.19 2.99 22.89 1,209.20 11.83 1,204.63 10.56 67.3784.74 544,873.496,031,887.351,154.23 0.95 30.74 1,309.20 13.14 1,302.27 13.95 88.6877.53 544,894.776,031,890.871,251.87 2.03 40.52 1,409.20 16.47 1,398.96 22.44 112.6264.83 544,918.666,031,899.511,348.56 4.63 55.95 1,509.20 17.21 1,494.68 36.12 138.1158.85 544,944.076,031,913.341,444.28 1.88 76.80 1,609.20 17.56 1,590.11 52.33 163.2055.44 544,969.056,031,929.701,539.71 1.08 99.93 1,709.20 19.11 1,685.04 71.32 188.2450.41 544,993.986,031,948.841,634.64 2.21 125.70 1,809.20 20.77 1,779.05 94.37 213.3244.65 545,018.916,031,972.041,728.65 2.57 155.34 1,909.20 22.54 1,871.99 121.59 238.2040.40 545,043.636,031,999.401,821.59 2.36 188.88 1,959.20 24.64 1,917.82 137.19 250.7237.23 545,056.066,032,015.071,867.42 4.91 207.57 2,009.20 26.50 1,962.92 154.61 263.4435.10 545,068.676,032,032.571,912.52 4.15 228.06 2,109.20 28.78 2,051.50 193.13 289.2832.71 545,094.286,032,071.242,001.10 2.53 272.65 2,209.20 31.95 2,137.78 236.31 315.5329.99 545,120.266,032,114.582,087.38 3.45 321.81 2,309.20 33.77 2,221.77 283.40 342.4829.59 545,146.926,032,161.822,171.37 1.83 374.90 2,409.20 33.72 2,304.93 331.88 369.6028.86 545,173.756,032,210.462,254.53 0.41 429.37 2,509.20 33.36 2,388.28 380.42 395.9928.19 545,199.846,032,259.152,337.88 0.52 483.67 2,609.20 32.88 2,472.03 428.45 422.0428.78 545,225.606,032,307.332,421.63 0.58 537.38 2,709.20 33.97 2,555.49 477.05 447.9627.38 545,251.226,032,356.082,505.09 1.34 591.59 2,809.20 33.91 2,638.45 526.60 473.6927.51 545,276.656,032,405.782,588.05 0.09 646.65 2,909.20 33.45 2,721.67 575.68 499.5027.96 545,302.166,032,455.022,671.27 0.52 701.28 3,009.20 33.30 2,805.18 624.11 525.5928.67 545,327.966,032,503.602,754.78 0.42 755.39 3,059.20 33.91 2,846.82 648.41 538.8328.50 545,341.056,032,527.972,796.42 1.23 782.58 3,109.20 35.27 2,887.98 673.39 552.3128.19 545,354.376,032,553.032,837.58 2.74 810.49 3,159.20 36.14 2,928.58 699.17 565.9827.69 545,367.896,032,578.892,878.18 1.84 839.23 3,209.20 37.17 2,968.69 725.62 579.8227.56 545,381.576,032,605.422,918.29 2.07 868.65 3,259.20 37.12 3,008.55 752.46 593.6426.93 545,395.236,032,632.342,958.15 0.77 898.43 3,309.20 36.86 3,048.49 779.22 607.3827.42 545,408.806,032,659.182,998.09 0.79 928.12 3,359.20 38.55 3,088.04 806.45 621.3026.77 545,422.566,032,686.493,037.64 3.47 958.31 3,409.20 40.16 3,126.70 834.73 635.6426.99 545,436.726,032,714.853,076.30 3.23 989.62 3,459.20 41.80 3,164.45 863.87 650.6527.51 545,451.566,032,744.093,114.05 3.35 1,021.98 3,509.20 43.12 3,201.34 893.75 666.3627.96 545,467.096,032,774.053,150.94 2.71 1,055.23 3,559.20 44.41 3,237.44 924.36 682.4727.54 545,483.006,032,804.753,187.04 2.64 1,089.31 3,609.20 45.17 3,272.93 955.65 698.6327.11 545,498.986,032,836.143,222.53 1.64 1,124.05 3,659.20 46.39 3,307.80 987.70 714.6626.04 545,514.826,032,868.283,257.40 2.88 1,159.48 7/21/2020 5:44:46PM COMPASS 5000.15 Build 91E Page 3 Superceded by WP08 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-54 As-built RKB @ 50.40usft Design:MPU L-21A WP06 Database:NORTH US + CANADA MD Reference:MPU L-54 As-built RKB @ 50.40usft North Reference: Well Plan: MPL-21 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 3,291.63 Vert Section 3,709.20 47.20 3,342.03 1,020.52 730.5125.50 545,530.466,032,901.193,291.63 1.80 1,195.58 3,759.20 48.91 3,375.45 1,054.23 746.2124.46 545,545.956,032,935.003,325.05 3.75 1,232.48 3,809.20 50.74 3,407.71 1,089.07 761.8824.00 545,561.426,032,969.923,357.31 3.73 1,270.45 3,859.20 52.09 3,438.89 1,124.74 777.8524.22 545,577.176,033,005.693,388.49 2.72 1,309.30 3,909.20 52.96 3,469.31 1,160.99 793.9923.79 545,593.096,033,042.033,418.91 1.87 1,348.76 3,959.20 53.52 3,499.23 1,197.56 810.3424.40 545,609.226,033,078.693,448.83 1.49 1,388.58 4,009.20 54.26 3,528.70 1,234.29 827.1524.76 545,625.806,033,115.523,478.30 1.59 1,428.70 4,059.20 55.10 3,557.61 1,271.26 844.4025.27 545,642.836,033,152.593,507.21 1.87 1,469.18 4,109.20 56.48 3,585.72 1,308.73 861.8724.73 545,660.076,033,190.173,535.32 2.90 1,510.21 4,159.20 57.79 3,612.85 1,346.88 879.4324.69 545,677.406,033,228.423,562.45 2.62 1,551.91 4,209.20 58.85 3,639.11 1,385.52 897.2524.84 545,694.986,033,267.163,588.71 2.14 1,594.15 4,259.20 59.44 3,664.75 1,424.71 914.7523.28 545,712.246,033,306.453,614.35 2.93 1,636.82 4,309.20 60.75 3,689.68 1,464.63 931.6222.56 545,728.886,033,346.473,639.28 2.90 1,680.00 4,359.20 61.72 3,713.74 1,505.15 948.3522.31 545,745.366,033,387.083,663.34 1.99 1,723.69 4,409.20 63.34 3,736.80 1,546.19 965.1822.28 545,761.946,033,428.223,686.40 3.24 1,767.92 4,459.20 64.19 3,758.91 1,587.67 982.2422.44 545,778.756,033,469.793,708.51 1.72 1,812.63 4,509.20 65.42 3,780.19 1,629.61 999.2121.63 545,795.476,033,511.833,729.79 2.86 1,857.75 4,559.20 66.21 3,800.68 1,672.06 1,015.9021.28 545,811.896,033,554.383,750.28 1.70 1,903.28 4,609.20 68.03 3,820.11 1,715.03 1,032.4920.96 545,828.236,033,597.443,769.71 3.69 1,949.27 4,709.20 71.03 3,855.08 1,802.91 1,064.9219.56 545,860.126,033,685.513,804.68 3.27 2,042.86 4,809.20 70.21 3,888.27 1,891.70 1,096.7619.89 545,891.426,033,774.493,837.87 0.88 2,137.15 4,909.20 71.72 3,920.88 1,980.53 1,129.0820.10 545,923.206,033,863.503,870.48 1.52 2,231.61 5,009.20 69.54 3,954.05 2,069.11 1,161.5420.15 545,955.126,033,952.263,903.65 2.18 2,325.87 5,109.20 71.09 3,987.73 2,157.49 1,194.0120.20 545,987.066,034,040.823,937.33 1.55 2,419.95 5,209.20 72.04 4,019.35 2,246.55 1,226.6920.10 546,019.206,034,130.073,968.95 0.95 2,514.74 5,309.20 71.39 4,050.73 2,335.63 1,259.5420.38 546,051.506,034,219.354,000.33 0.70 2,609.61 5,409.20 71.42 4,082.61 2,424.60 1,292.2319.97 546,083.656,034,308.504,032.21 0.39 2,704.32 5,509.20 71.96 4,114.03 2,514.00 1,324.1719.35 546,115.056,034,398.084,063.63 0.80 2,799.21 5,609.20 72.20 4,144.80 2,603.80 1,355.6219.26 546,145.966,034,488.064,094.40 0.25 2,894.33 5,709.20 72.90 4,174.79 2,694.04 1,386.5618.59 546,176.356,034,578.474,124.39 0.95 2,989.71 5,809.20 72.70 4,204.36 2,784.64 1,416.8318.36 546,206.076,034,669.254,153.96 0.30 3,085.23 5,909.20 71.70 4,234.93 2,875.00 1,446.8618.41 546,235.566,034,759.774,184.53 1.00 3,180.44 6,009.20 71.69 4,266.33 2,965.12 1,476.7218.25 546,264.876,034,850.074,215.93 0.15 3,275.38 6,109.20 71.95 4,297.53 3,055.27 1,506.7218.56 546,294.326,034,940.384,247.13 0.39 3,370.38 6,209.20 71.29 4,329.07 3,145.32 1,536.6518.21 546,323.706,035,030.614,278.67 0.74 3,465.28 6,309.20 71.83 4,360.70 3,235.32 1,566.6418.65 546,353.156,035,120.784,310.30 0.68 3,560.14 6,409.20 71.03 4,392.54 3,325.08 1,597.1318.87 546,383.096,035,210.714,342.14 0.83 3,654.92 6,509.20 72.29 4,424.01 3,414.76 1,628.2219.37 546,413.646,035,300.574,373.61 1.35 3,749.82 6,609.20 71.23 4,455.31 3,504.55 1,659.1518.64 546,444.026,035,390.544,404.91 1.27 3,844.77 6,709.20 72.92 4,486.08 3,594.93 1,688.8817.79 546,473.216,035,481.084,435.68 1.87 3,939.91 6,809.20 71.85 4,516.35 3,685.60 1,718.2618.11 546,502.036,035,571.924,465.95 1.11 4,035.22 6,909.20 71.21 4,548.03 3,776.18 1,746.3816.39 546,529.616,035,662.664,497.63 1.75 4,130.06 7,009.20 72.14 4,579.47 3,866.78 1,774.6818.29 546,557.366,035,753.424,529.07 2.03 4,224.98 7,059.20 71.55 4,595.05 3,911.85 1,789.7318.64 546,572.136,035,798.574,544.65 1.35 4,272.48 7,138.04 72.30 4,619.51 3,982.89 1,813.6018.50 546,595.576,035,869.764,569.11 0.97 4,347.43 7/21/2020 5:44:46PM COMPASS 5000.15 Build 91E Page 4 Superceded by WP08 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-54 As-built RKB @ 50.40usft Design:MPU L-21A WP06 Database:NORTH US + CANADA MD Reference:MPU L-54 As-built RKB @ 50.40usft North Reference: Well Plan: MPL-21 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 4,588.62 Vert Section 7,201.77 72.06 4,639.02 4,040.34 1,833.1119.03 546,614.746,035,927.314,588.62 0.88 4,408.09 7,253.20 71.91 4,654.92 4,086.70 1,848.6918.11 546,630.036,035,973.764,604.52 1.72 4,457.00 9 5/8" 7,401.35 71.52 4,701.40 4,221.36 1,889.3315.47 546,669.866,036,108.654,651.00 1.72 4,597.63 7,495.62 70.82 4,731.83 4,306.79 1,915.0418.03 546,695.056,036,194.234,681.43 2.68 4,686.83 7,592.23 70.26 4,764.02 4,392.73 1,945.2020.65 546,724.686,036,280.344,713.62 2.62 4,777.88 7,686.61 71.85 4,794.66 4,475.96 1,977.4621.72 546,756.446,036,363.754,744.26 2.00 4,866.99 7,778.79 71.46 4,823.68 4,557.52 2,009.1520.75 546,787.646,036,445.494,773.28 1.08 4,954.34 7,870.42 71.37 4,852.88 4,638.98 2,039.2719.83 546,817.266,036,527.124,802.48 0.96 5,041.11 7,967.86 70.91 4,884.39 4,726.52 2,068.1916.73 546,845.656,036,614.834,833.99 3.05 5,133.30 8,062.74 70.72 4,915.57 4,811.78 2,095.7319.08 546,872.686,036,700.254,865.17 2.35 5,222.91 8,157.23 70.53 4,946.92 4,895.70 2,125.7720.31 546,902.216,036,784.344,896.52 1.24 5,312.00 8,252.02 71.21 4,977.98 4,979.89 2,156.3119.57 546,932.246,036,868.704,927.58 1.03 5,401.50 8,347.85 71.52 5,008.60 5,065.38 2,186.9319.84 546,962.346,036,954.364,958.20 0.42 5,492.26 8,443.42 71.21 5,039.14 5,150.42 2,218.0720.38 546,992.966,037,039.584,988.74 0.63 5,582.75 8,535.66 72.01 5,068.24 5,231.98 2,249.8222.15 547,024.216,037,121.335,017.84 2.02 5,670.12 8,630.44 71.53 5,097.89 5,315.40 2,283.6722.03 547,057.556,037,204.935,047.49 0.52 5,759.90 8,726.11 71.22 5,128.45 5,398.75 2,319.3124.27 547,092.696,037,288.495,078.05 2.24 5,850.17 8,818.07 70.63 5,158.50 5,477.94 2,355.1124.39 547,128.016,037,367.895,108.10 0.65 5,936.53 8,913.95 71.38 5,189.71 5,560.49 2,392.6024.46 547,165.006,037,450.655,139.31 0.79 6,026.60 9,008.81 70.92 5,220.36 5,642.52 2,429.0623.47 547,200.966,037,532.905,169.96 1.10 6,115.87 9,102.62 71.96 5,250.22 5,724.06 2,464.5623.58 547,235.966,037,614.645,199.82 1.11 6,204.37 9,197.92 71.57 5,280.04 5,807.05 2,500.6923.47 547,271.596,037,697.845,229.64 0.42 6,294.45 9,292.86 71.81 5,309.87 5,890.55 2,534.5920.73 547,304.986,037,781.535,259.47 2.75 6,384.33 9,388.00 71.18 5,340.07 5,975.05 2,566.2120.29 547,336.086,037,866.225,289.67 0.79 6,474.45 9,484.05 72.15 5,370.28 6,060.41 2,598.2320.83 547,367.586,037,951.765,319.88 1.14 6,565.53 9,599.49 71.44 5,406.35 6,162.93 2,637.1620.76 547,405.896,038,054.505,355.95 0.62 6,675.05 9,694.60 70.85 5,437.09 6,247.41 2,668.2019.59 547,436.426,038,139.165,386.69 1.32 6,764.98 9,789.75 71.60 5,467.71 6,331.92 2,699.4020.93 547,467.116,038,223.855,417.31 1.55 6,854.98 9,884.75 71.25 5,497.97 6,416.30 2,730.8519.96 547,498.056,038,308.415,447.57 1.04 6,944.94 9,978.94 70.39 5,528.92 6,499.72 2,761.7720.71 547,528.466,038,392.005,478.52 1.18 7,033.82 10,072.99 71.24 5,559.83 6,583.02 2,792.6019.92 547,558.796,038,475.485,509.43 1.20 7,122.57 10,167.42 72.30 5,589.37 6,667.26 2,823.3720.20 547,589.046,038,559.905,538.97 1.16 7,212.19 10,258.80 71.82 5,617.51 6,749.10 2,852.7019.23 547,617.876,038,641.915,567.11 1.14 7,299.09 10,354.56 71.12 5,647.95 6,834.95 2,882.2718.79 547,646.936,038,727.925,597.55 0.85 7,389.86 10,449.42 71.34 5,678.47 6,919.58 2,912.3220.30 547,676.466,038,812.735,628.07 1.52 7,479.64 10,500.00 71.05 5,694.78 6,964.43 2,929.0820.69 547,692.956,038,857.675,644.38 0.92 7,527.47 KOP : Start Dir 12.3º/100' : 10500' MD, 5694.78'TVD : 60° RT TF - 7" TOW 10,517.00 72.10 5,700.15 6,979.42 2,935.0322.59 547,698.816,038,872.705,649.75 12.30 7,543.56 End Dir : 10517' MD, 5700.15' TVD 10,547.00 72.10 5,709.37 7,005.78 2,945.9922.59 547,709.616,038,899.125,658.97 0.00 7,572.01 Start Dir 4º/100' : 10547' MD, 5709.37'TVD 10,600.00 72.53 5,725.47 7,052.76 2,964.5020.41 547,727.836,038,946.205,675.07 4.00 7,622.41 10,700.00 73.41 5,754.76 7,143.48 2,994.6216.33 547,757.406,039,037.105,704.36 4.00 7,717.99 10,800.00 74.36 5,782.52 7,236.56 3,018.3412.28 547,780.566,039,130.305,732.12 4.00 7,813.85 7/21/2020 5:44:46PM COMPASS 5000.15 Build 91E Page 5 Superceded by WP08 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-54 As-built RKB @ 50.40usft Design:MPU L-21A WP06 Database:NORTH US + CANADA MD Reference:MPU L-54 As-built RKB @ 50.40usft North Reference: Well Plan: MPL-21 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 5,758.22 Vert Section 10,900.00 75.39 5,808.62 7,331.52 3,035.568.28 547,797.216,039,225.365,758.22 4.00 7,909.52 11,000.00 76.49 5,832.92 7,427.92 3,046.194.31 547,807.256,039,321.815,782.52 4.00 8,004.52 11,014.51 76.65 5,836.29 7,442.00 3,047.183.74 547,808.166,039,335.895,785.89 4.00 8,018.22 End Dir : 11014.51' MD, 5836.29' TVD 11,100.00 76.65 5,856.03 7,525.00 3,052.613.74 547,813.096,039,418.925,805.63 0.00 8,098.88 11,200.00 76.65 5,879.12 7,622.09 3,058.963.74 547,818.856,039,516.045,828.72 0.00 8,193.23 11,300.00 76.65 5,902.20 7,719.18 3,065.313.74 547,824.626,039,613.155,851.80 0.00 8,287.57 11,400.00 76.65 5,925.29 7,816.27 3,071.663.74 547,830.386,039,710.275,874.89 0.00 8,381.92 11,500.00 76.65 5,948.38 7,913.36 3,078.013.74 547,836.146,039,807.395,897.98 0.00 8,476.27 11,600.00 76.65 5,971.47 8,010.45 3,084.363.74 547,841.916,039,904.515,921.07 0.00 8,570.61 11,700.00 76.65 5,994.55 8,107.55 3,090.713.74 547,847.676,040,001.635,944.15 0.00 8,664.96 11,800.00 76.65 6,017.64 8,204.64 3,097.063.74 547,853.436,040,098.745,967.24 0.00 8,759.31 11,900.00 76.65 6,040.73 8,301.73 3,103.413.74 547,859.206,040,195.865,990.33 0.00 8,853.66 12,000.00 76.65 6,063.81 8,398.82 3,109.763.74 547,864.966,040,292.986,013.41 0.00 8,948.00 12,100.00 76.65 6,086.90 8,495.91 3,116.113.74 547,870.736,040,390.106,036.50 0.00 9,042.35 12,200.00 76.65 6,109.99 8,593.00 3,122.463.74 547,876.496,040,487.226,059.59 0.00 9,136.70 12,252.95 76.65 6,122.21 8,644.41 3,125.823.74 547,879.546,040,538.646,071.81 0.00 9,186.65 Start Dir 4º/100' : 12252.95' MD, 6122.21'TVD 12,300.00 74.77 6,133.83 8,689.91 3,128.783.70 547,882.236,040,584.156,083.43 4.00 9,230.86 12,400.00 70.77 6,163.44 8,785.20 3,134.873.61 547,887.746,040,679.476,113.04 4.00 9,323.42 12,500.00 66.77 6,199.64 8,878.22 3,140.673.52 547,892.986,040,772.516,149.24 4.00 9,413.72 12,600.00 62.77 6,242.26 8,968.50 3,146.143.42 547,897.906,040,862.816,191.86 4.00 9,501.31 12,700.00 58.77 6,291.07 9,055.60 3,151.263.31 547,902.506,040,949.936,240.67 4.00 9,585.78 12,800.00 54.77 6,345.85 9,139.10 3,156.013.20 547,906.756,041,033.456,295.45 4.00 9,666.70 12,900.00 50.78 6,406.34 9,218.59 3,160.363.07 547,910.626,041,112.966,355.94 4.00 9,743.69 13,000.00 46.78 6,472.22 9,293.69 3,164.302.92 547,914.106,041,188.076,421.82 4.00 9,816.36 13,100.00 42.78 6,543.19 9,364.02 3,167.792.76 547,917.176,041,258.426,492.79 4.00 9,884.37 13,200.00 38.78 6,618.90 9,429.26 3,170.832.57 547,919.816,041,323.676,568.50 4.00 9,947.38 13,300.00 34.78 6,698.97 9,489.07 3,173.402.34 547,922.026,041,383.486,648.57 4.00 10,005.09 13,400.00 30.79 6,783.03 9,543.16 3,175.492.06 547,923.786,041,437.596,732.63 4.00 10,057.21 13,419.68 30.00 6,800.00 9,553.11 3,175.842.00 547,924.086,041,447.546,749.60 4.00 10,066.79 End Dir : 13419.68' MD, 6800' TVD 13,423.60 30.00 6,803.40 9,555.07 3,175.912.00 547,924.136,041,449.506,753.00 0.00 10,068.68 HRZ 13,427.07 30.00 6,806.40 9,556.81 3,175.972.00 547,924.186,041,451.236,756.00 0.00 10,070.34 KLB 13,468.64 30.00 6,842.40 9,577.58 3,176.692.00 547,924.786,041,472.016,792.00 0.00 10,090.33 KLGM 13,500.00 30.00 6,869.56 9,593.25 3,177.242.00 547,925.246,041,487.686,819.16 0.00 10,105.41 13,600.00 30.00 6,956.16 9,643.22 3,178.982.00 547,926.686,041,537.656,905.76 0.00 10,153.50 13,616.44 30.00 6,970.40 9,651.43 3,179.272.00 547,926.926,041,545.876,920.00 0.00 10,161.41 KUP_D 13,700.00 30.00 7,042.77 9,693.19 3,180.732.00 547,928.126,041,587.636,992.37 0.00 10,201.59 13,760.78 30.00 7,095.40 9,723.56 3,181.792.00 547,929.006,041,618.007,045.00 0.00 10,230.82 7/21/2020 5:44:46PM COMPASS 5000.15 Build 91E Page 6 Superceded by WP08 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-54 As-built RKB @ 50.40usft Design:MPU L-21A WP06 Database:NORTH US + CANADA MD Reference:MPU L-54 As-built RKB @ 50.40usft North Reference: Well Plan: MPL-21 True Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Map Northing (usft) Map Easting (usft) +N/-S (usft) Planned Survey Vertical Depth (usft) TVDss usft DLS 7,047.00 Vert Section 13,763.09 30.00 7,097.40 9,724.71 3,181.832.00 547,929.036,041,619.157,047.00 0.00 10,231.93 KUP_C 13,771.17 30.00 7,104.40 9,728.75 3,181.972.00 547,929.156,041,623.197,054.00 0.00 10,235.82 KUP_B6 13,800.00 30.00 7,129.37 9,743.16 3,182.472.00 547,929.576,041,637.607,078.97 0.00 10,249.68 13,887.79 30.00 7,205.40 9,787.03 3,184.012.00 547,930.836,041,681.487,155.00 0.00 10,291.90 KUP_A3 13,900.00 30.00 7,215.97 9,793.13 3,184.222.00 547,931.016,041,687.587,165.57 0.00 10,297.77 13,905.11 30.00 7,220.40 9,795.68 3,184.312.00 547,931.086,041,690.137,170.00 0.00 10,300.23 KUP_A2 13,933.98 30.00 7,245.40 9,810.11 3,184.812.00 547,931.506,041,704.567,195.00 0.00 10,314.11 KUP_A1 13,999.80 30.00 7,302.40 9,843.00 3,185.962.00 547,932.456,041,737.457,252.00 0.00 10,345.77 KUP_A_BASE 14,000.00 30.00 7,302.57 9,843.10 3,185.962.00 547,932.456,041,737.557,252.17 0.00 10,345.86 14,060.78 30.00 7,355.21 9,873.47 3,187.022.00 547,933.336,041,767.927,304.81 0.00 10,375.09 Total Depth : 14060.78' MD, 7355.21' TVD Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Tar gets Dip Angle (°) Dip Dir. (°) A8-I1 7,095.40 6,041,618.00 547,929.009,723.56 3,181.790.00 0.00 -plan hits target center - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 7" TOW5,694.7810,500.00 78-1/2 4 1/2" x 6 1/8"7,355.2114,060.78 4-1/2 6-1/8 7/21/2020 5:44:46PM COMPASS 5000.15 Build 91E Page 7 Superceded by WP08 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt L Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPL-21 MPU L-21A Survey Calculation Method:Minimum Curvature MPU L-54 As-built RKB @ 50.40usft Design:MPU L-21A WP06 Database:NORTH US + CANADA MD Reference:MPU L-54 As-built RKB @ 50.40usft North Reference: Well Plan: MPL-21 True Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations Vertical Depth SS 13,887.79 7,205.40 KUP_A3 13,468.64 6,842.40 KLGM 13,616.44 6,970.40 KUP_D 13,423.60 6,803.40 HRZ 13,933.98 7,245.40 KUP_A1 13,763.09 7,097.40 KUP_C 13,999.80 7,302.40 KUP_A_BASE 13,427.07 6,806.40 KLB 13,905.11 7,220.40 KUP_A2 13,771.17 7,104.40 KUP_B6 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 10,500.00 5,694.78 6,964.43 2,929.08 KOP : Start Dir 12.3º/100' : 10500' MD, 5694.78'TVD : 60° RT TF 10,517.00 5,700.15 6,979.42 2,935.03 End Dir : 10517' MD, 5700.15' TVD 10,547.00 5,709.37 7,005.78 2,945.99 Start Dir 4º/100' : 10547' MD, 5709.37'TVD 11,014.51 5,836.29 7,442.00 3,047.18 End Dir : 11014.51' MD, 5836.29' TVD 12,252.95 6,122.21 8,644.41 3,125.82 Start Dir 4º/100' : 12252.95' MD, 6122.21'TVD 13,419.68 6,800.00 9,553.11 3,175.84 End Dir : 13419.68' MD, 6800' TVD 14,060.78 7,355.21 9,873.47 3,187.02 Total Depth : 14060.78' MD, 7355.21' TVD 7/21/2020 5:44:46PM COMPASS 5000.15 Build 91E Page 8 Superceded by WP08 21 July, 2020Milne PointM Pt L PadPlan: MPL-21MPU L-21A5002922629MPU L-21A WP06Reference Design: M Pt L Pad - Plan: MPL-21 - MPU L-21A - MPU L-21A WP06Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,031,876.39 N, 544,806.19 E (70° 29' 52.64" N, 149° 38' 00.90" W)Datum Height: MPU L-54 As-built RKB @ 50.40usftScan Range: 10,500.00 to 14,060.78 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00SupercededbyW Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPL-21 - MPU L-21A WP06Comparison Well Name - Wellbore Name - Design@MeasuredDepth(usft)MinimumDistance(usft)EllipseSeparation(usft)@MeasuredDepthusftClearanceFactorScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftSite NameScan Range: 10,500.00 to 14,060.78 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt L Pad - Plan: MPL-21 - MPU L-21A - MPU L-21A WP06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt F PadMPF-49 - MPF-49 - MPF-491,398.74 12,625.00 1,204.10 10,764.03 7.18612,625.00Clearance Factor Pass - MPF-49 - MPF-49 - MPF-491,357.40 12,875.00 1,174.07 10,951.07 7.40412,875.00Ellipse Separation Pass - MPF-49 - MPF-49 - MPF-491,355.35 12,944.12 1,176.17 11,006.05 7.56412,944.12Centre Distance Pass - MPF-57 - MPF-57 - MPF-571,499.07 11,650.00 1,367.47 9,916.13 11.39111,650.00Clearance Factor Pass - MPF-57 - MPF-57 - MPF-571,295.23 12,450.00 1,200.77 10,571.48 13.71212,450.00Ellipse Separation Pass - MPF-57 - MPF-57 - MPF-571,294.32 12,492.34 1,201.37 10,604.63 13.92512,492.34Centre Distance Pass - MPF-57 - MPF-57A - MPF-57A1,467.61 11,975.00 1,341.76 10,171.18 11.66211,975.00Clearance Factor Pass - MPF-57 - MPF-57A - MPF-57A1,316.00 12,575.00 1,216.22 10,752.82 13.18912,575.00Ellipse Separation Pass - MPF-57 - MPF-57A - MPF-57A1,314.49 12,630.51 1,217.06 10,794.01 13.49112,630.51Centre Distance Pass - MPF-57 - MPF-57APB1 - MPF-57APB11,467.61 11,975.00 1,341.76 10,171.18 11.66211,975.00Clearance Factor Pass - MPF-57 - MPF-57APB1 - MPF-57APB11,316.00 12,575.00 1,216.22 10,752.82 13.18912,575.00Ellipse Separation Pass - MPF-57 - MPF-57APB1 - MPF-57APB11,314.49 12,630.51 1,217.06 10,794.01 13.49112,630.51Centre Distance Pass - MPU F-116 - MPU F-116 - MPU F-1161,067.52 12,363.77 984.92 10,076.80 12.92412,363.77Centre Distance Pass - MPU F-116 - MPU F-116 - MPU F-1161,068.27 12,400.00 984.55 10,101.34 12.76012,400.00Ellipse Separation Pass - MPU F-116 - MPU F-116 - MPU F-1161,261.66 13,000.00 1,144.83 10,561.48 10.79813,000.00Clearance Factor Pass - M Pt L PadMPL-14 - MPL-14 - MPL-141,465.70 11,394.38 1,071.32 10,710.00 3.71611,394.38Centre Distance Pass - MPL-14 - MPL-14 - MPL-141,479.22 13,825.00 1,064.91 12,880.00 3.57013,825.00Clearance Factor Pass - MPL-14 - MPL-14 - MPL-141,476.77 13,875.00 1,063.69 12,880.00 3.57513,875.00Ellipse Separation Pass - MPL-29 - MPL-29 - MPL-29987.78 10,500.00 680.00 10,145.81 3.20910,500.00Clearance Factor Pass - MPU L-41 - MPU L-41 - MPU L-411,139.87 10,500.00 997.26 9,850.60 7.99310,500.00Clearance Factor Pass - MPU L-41 - MPU L-41PB1 - MPU L-41PB11,192.42 10,500.00 1,043.52 9,847.83 8.00810,500.00Clearance Factor Pass - MPU L-55 - MPU L-55 - MPU L-55345.20 10,780.16 139.99 10,189.08 1.68210,780.16Centre Distance Pass - MPU L-55 - MPU L-55 - MPU L-55349.29 10,850.00 134.37 10,245.87 1.62510,850.00Clearance Factor Pass - Plan: MPL-21 - MPL-21 - MPL-2115.27 10,800.00 7.93 10,794.88 2.08110,800.00Clearance Factor Pass - 21 July, 2020-17:49COMPASSPage 2 of 5SupercededbyW Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPL-21 - MPU L-21A WP06Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool109.20 7,059.203_Gyro-CT_Drill pipe7,138.04 10,500.003_MWD10,500.00 10,900.00 MPU L-21A WP06 3_MWD_Interp Azi+Sag10,900.00 14,060.78 MPU L-21A WP06 3_MWD+IFR2+MS+SagEllipse error terms are correlated across survey tool tie-on points.Separation is the actual distance between ellipsoids.Calculated ellipses incorporate surface errors.Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).Distance Between centres is the straight line distance between wellbore centres.All station coordinates were calculated using the Minimum Curvature method.21 July, 2020-17:49COMPASSPage 3 of 5SupercededbyW 0.001.002.003.004.00Separation Factor10575 10800 11025 11250 11475 11700 11925 12150 12375 12600 12825 13050 13275 13500 13725 13950 14175 14400 14625 14850Measured Depth (450 usft/in)MPU L-55MPL-21No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPL-21 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 16.70+N/-S +E/-W Northing Easting Latittude Longitude0.000.006031876.39544806.1970° 29' 52.643 N149° 38' 0.902 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPL-21, True NorthVertical (TVD) Reference:MPU L-54 As-built RKB @ 50.40usftMeasured Depth Reference:MPU L-54 As-built RKB @ 50.40usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-07-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool109.20 7059.20 MPL-21 Gyrodata NSG in 5" DP (MPL-21) 3_Gyro-CT_Drill pipe7138.04 10500.00 MPL-21 MWD - Prod HS (MPL-21) 3_MWD10500.00 10900.00 MPU L-21A WP06 (MPU L-21A) 3_MWD_Interp Azi+Sag10900.00 14060.78 MPU L-21A WP06 (MPU L-21A) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)10575 10800 11025 11250 11475 11700 11925 12150 12375 12600 12825 13050 13275 13500 13725 13950 14175 14400 14625 14850Measured Depth (450 usft/in)NO GLOBAL FILTER: Using user defined selection & filtering criteria10500.00 To 14060.78Project: Milne PointSite: M Pt L PadWell: Plan: MPL-21Wellbore: MPU L-21APlan: MPU L-21A WP06CASING DETAILSTVD TVDSS MD Size Name5694.78 5644.38 10500.00 7 7" TOW7355.21 7304.81 14060.78 4-1/2 4 1/2" x 6 1/8"SupercededbyW _____________________________________________________________________________________ Revised By: JNL 7/21/2020 PROPOSED SCHEMATIC Milne Point Unit Well: MPU L-21A Last Completed: 5/16/1996 PTD: TBD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112’ 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,249’ 7" Intermediate 26 / L-80 / BTC 6.276 Surface 10,500’ 4-1/2” Liner 12.6 / L-80 / TXP 3.958 10,050’ 14,060’ TUBING DETAIL 2-7/8”x 2-3/8” Tubing 6.6 / L-80 / EUE 8rd 6.4 / L-80 / EUE 8rd 2.441, 1.995 Surface 13,700’ JEWELRY DETAIL No Depth Item 1 TBD 3.5” XN Nipple w/ RHC Plug – MIN ID = 2.750” 2 TBD 7” x 4-1/2” Liner Top Packer 3 TBD Production Packer 4 TBD WLEG – Bottom @ TBD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Perforation Summary: OPEN HOLE / CEMENT DETAIL 24" 250 sx of Arcticset I 12-1/4" 1,396 sx PF “E”, 250 sx Class “G”, 150 sx PF ‘E 6-1/8” 131.2 ft3 Class “G” WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 77 deg Hole Angle through perforations = 30 TREE & WELLHEAD Tree 3-1/8” – 5M AlloyTree ‘FL’ Wellhead FMC 11” x 11” 5M, Gen 5 w/ 11” x 3.5” FMC Tubing Hanger, w/ NSCT Threads Top and bottom and 3” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22629-01-00 Completed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Seamount, Jr.Digitally signed by Daniel T. Seamount, Jr. Date: 2020.09.02 11:47:13 -08'00'JMP9/2/2020JLC 9/2/2020