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Home My WebLink About220-055MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC I-37 MILNE PT UNIT I-37 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 I-37 50-029-23682-00-00 220-055-0 W SPT 3811 2200550 1500 272 271 272 272 4YRTST P Brian Bixby 8/19/2024 Monobore Completion 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 I-37 Inspection Date: Tubing OA Packer Depth 238 1752 1690 1671IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240820131906 BBL Pumped:2.2 BBL Returned:2.2 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 10:44:13 -08'00' DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23682-00-00Well Name/No. MILNE PT UNIT I-37Completion Status1WINJCompletion Date7/19/2020Permit to Drill2200550Operator Hilcorp Alaska, LLCMD15797TVD4000Current Status1WINJ10/14/2020UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, ABG, DGR, EWR, ADR MD & TVD, PB1: ROP, AGR, ABG, DGR, EWR, ADR MD & TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF10/5/2020150 15797 Electronic Data Set, Filename: MPU I-37 LWD Final.las34030EDDigital DataDF10/5/20205683 15760 Electronic Data Set, Filename: MPU I-37 ADR Quadrants All Curves.las34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final MD.cgm34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final TVD.cgm34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37i_Definitive Survey Report.pdf34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37i_DSR.txt34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37i_GIS.txt34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final MD.emf34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final TVD.emf34030EDDigital DataDF10/5/2020 Electronic File: MPU_I-37_Geosteering.dlis34030EDDigital DataDF10/5/2020 Electronic File: MPU_I-37_Geosteering.ver34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final MD.pdf34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final TVD.pdf34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final MD.tif34030EDDigital DataDF10/5/2020 Electronic File: MPU I-37 LWD Final TVD.tif34030EDDigital Data0 0 2200550 MILNE PT UNIT I-37 LOG HEADERS34030LogLog Header Scans0 0 2200550 MILNE PT UNIT I-37 PB1 LOG HEADERS34031LogLog Header ScansDF10/5/2020150 12809 Electronic Data Set, Filename: MPU I-37PB1 LWD Final.las34031EDDigital DataWednesday, October 14, 2020AOGCCPage 1 of 3PB1MPU I-37 LWDFinal.lasMPU I-37PB1LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23682-00-00Well Name/No. MILNE PT UNIT I-37Completion Status1WINJCompletion Date7/19/2020Permit to Drill2200550Operator Hilcorp Alaska, LLCMD15797TVD4000Current Status1WINJ10/14/2020UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDF10/5/20205683 12771 Electronic Data Set, Filename: MPU I-37PB1 ADR Quadrants All Curves.las34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final MD.cgm34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final TVD.cgm34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1_Definitive Survey Report.pdf34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1_DSR.txt34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1_GIS.txt34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final MD.emf34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final TVD.emf34031EDDigital DataDF10/5/2020 Electronic File: MPU_I-37PB1_Geosteering.dlis34031EDDigital DataDF10/5/2020 Electronic File: MPU_I-37PB1_Geosteering.ver34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final MD.pdf34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final TVD.pdf34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final MD.emf.tif34031EDDigital DataDF10/5/2020 Electronic File: MPU I-37PB1 LWD Final TVD.emf.tif34031EDDigital DataWednesday, October 14, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23682-00-00Well Name/No. MILNE PT UNIT I-37Completion Status1WINJCompletion Date7/19/2020Permit to Drill2200550Operator Hilcorp Alaska, LLCMD15797TVD4000Current Status1WINJ10/14/2020UICYesComments:Compliance Reviewed By:Date:Date CommentsDescriptionCompletion Date:7/19/2020Release Date:6/29/2020Wednesday, October 14, 2020AOGCCPage 3 of 3M. Guhl10/14/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: DATE 10/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-37 & MPU I-37PB1 (PTD 220-055) FINAL LWD Logs – EWR-M5, AGR, ADR, DGR, ABG, WELLBORE_PROFILE (MD/TVD) AND DEFINITIVE DIRECTIONAL SURVEY Main Folders: Sub-Folders: Received by the AOGCC 10/05/2020 PTD: 2200550 E-Set: 34031 Abby Bell 10/05/2020 David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: DATE 10/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-37 & MPU I-37PB1 (PTD 220-055) FINAL LWD Logs – EWR-M5, AGR, ADR, DGR, ABG, WELLBORE_PROFILE (MD/TVD) AND DEFINITIVE DIRECTIONAL SURVEY Main Folders: Sub-Folders: Received by the AOGCC 10/05/2020 PTD: 2200550 E-Set: 34030 Abby Bell 10/05/2020 MEMORANDUM TO: Jim Regg , t P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector 9(clj*7,1,) NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 27, 2020 SUBJECT: Mechanical Integrity Tests Mcorp Alaska, LLC I-37 MMNE PT UNIT 1-37 Ste: Inspector Reviewed B P.L Snpry j �32 Comm Well Name MILNE PT UNIT 1-37 API Well Number 50-029-23682-00-00 Inspector Name: Lou Laub -stein Permit Number: 220-055-0 Inspection Date: 8/22/2020 - IRsp Num: mi[LOL200823145834 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 37 Type Inj IW TVD 1 3811 'Tubing 631 _ 632 _ 631 630 ' pq D 2200550 Type Test I SPT Test psi 1500 IA 149 2518 ' 2427 2399 ' BBL Pumped: 3.4 'BBL Returned: 3.4 OA Interval INIlAL P/F P Notes: Initial MIT -IA Thursday, August 27, 2020 Page 1 of 1 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: 31.70' 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" X-56 154' L-80 1871' L-80 3814' 4-1/2"L-80 3964' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production:Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9-5/8"12-1/4" ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, Uncemented Screen Liner8-1/2" TUBING RECORD Liner Top Packer 5527'3-1/2" 9.3# L-80 SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Stg 2 L - 553 sx / T - 269 sx w/ Swell Packer Driven Surface 1931'Stg 1 L - 514 sx / T - 400 sx 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 7/19/2020 2334' FSL, 3801' FEL, Sec. 33, T13N, R10E, UM, AK 1841' FNL, 938' FWL, Sec. 21, T13N, R10E, UM, AK 220-055 Milne Point Field, Schrader Bluff Oil Pool 60.45' 13880' / 3964' 7/13/2020 6/29/2020 HOLE SIZE AMOUNT PULLED 33.90' 50-029-23682-00-00 MPU I-37 551570 6009449 1015' FNL, 783' FEL, Sec. 32, T13N, R10E, UM, AK CEMENTING RECORD 6011364 SETTING DEPTH TVD 6021108 BOTTOM TOP Surface Surface ROP, AGR, ABG, DGR, EWR, ADR MD & TVD PB1: ROP, AGR, ABG, DGR, EWR, ADR MD & TVD CASING WT. PER FT.GRADE 13.5# 549290 550917 TOP SETTING DEPTH MD Surface 5513' Per 20 AAC 25.283 (i)(2) attach electronic information 40# 13880' 1871' 3811' DEPTH SET (MD) 5513' / 3811' PACKER SET (MD/TVD) 129.5# 47# 154' 1931'5964' 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 4-1/2" Screen Liner 7/17/2020 ***Please see attached Schematic for detail*** Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl:Water-Bbl: ADL025906, 025517 & 315848 88-004 1810' / 1764' N/AN/A None 15797' / 4000' G s d 1 0 p d P l L (att Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Huey Winston at 11:23 am, Aug 12, 2020 Completion Date 7/19/2020 HEW RBDMS HEW 8/12/2020 5694' DLB 08/13/2020 0 DLB DSR-8/13/2020MGR10SEP2020 G Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 30' 30' 1840' 1794' Top of Productive Interval 5840' 3814' 1360' 1349' 2130' 2022' 4040' 3271' 5310' 3783' 5840' 3814' SB NB 5840' 3814' 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: General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: FORMATION TESTS Permafrost - Top 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 inc lination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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 SB NB Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): 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 SB NA SV5 SV1 Formation at total depth: Ugnu LA3 Plugback Summary, Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report 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 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). 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. 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. 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). N Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 8.10.2020Digitally 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: 2020.08.10 07:07:40 -08'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 7/30/20 Proposed Schematic Milne Point Unit Well: MPU I-37 PTD: 220-055 API: 50-029-23682-00-00 4-1/2” SOLID Liner Detail 4-1/2” SCREEN Liner Detail Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 5 5539’ 3813’ 5745’ 3815’ 2 5764’ 3814’ 5845’ 3814’ 34 5887’ 3814’ 7270’ 3829’ 7 7312’ 3831’ 7600’ 3833’ 8 7642’ 3832’ 7962’ 3835’ 13 8002’ 3835’ 8520’ 3843’ 10 8561’ 3843’ 8971’ 3860’ 12 9012’ 3863’ 9492’ 3893’ 20 9533’ 3896’ 10350’ 3903’ 25 10391’ 3905’ 11425’ 3919’ 8 11466’ 3920’ 11784’ 3930’ 16 11826’ 3930’ 12467’ 3943’ 12 12508’ 3944’ 12995’ 3957’ 6 13036’ 3959’ 13276’ 3962’ 9 13318’ 3962’ 13677’ 3962’ 4 13718’ 3963’ 13879’ 3964’ Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 1 5845’ 3814’ 5887’ 3814’ 1 7270’ 3829’ 7312’ 3831’ 1 7600’ 3833’ 7642’ 3832’ 1 7962’ 3835’ 8002’ 3835’ 1 8520’ 3843’ 8561’ 3843’ 1 8971’ 3860’ 9012’ 3863’ 1 9492’ 3893’ 9533’ 3896’ 1 10350’ 3903’ 10391’ 3905’ 1 11425’ 3919’ 11466’ 3920’ 1 11784’ 3930’ 11826’ 3930’ 1 12467’ 3943’ 12508’ 3944’ 1 12995’ 3957’ 13036’ 3959’ 1 13276’ 3962’ 13318’ 3962’ 1 13677’ 3962’ 13718’ 3963’ CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 129.5 / X-56 / Weld N/A Surface 154’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 1,931’ 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.679” 1,931’ 5,694’ 0.0758 4-1/2” Liner 250ђ Screens 13.5 / L-80 / Hyd 625 3.795” 5,513’ 13,880’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / EUE 8RD 2.867” Surf 5,527 0.0870 JEWELRY DETAIL No Top MD Item ID Upper Completion 1 4,763’ 3-1/2” C6 Gauge 400 BAR 150C w/ ¼” Wire 2.992” 2 4,814’ 3-1/2” XN Nipple, 2.813” Packing Bore, 2.75” No-Go, w/RHC 2.750” 3 5,514’ 8.26” No Go Locater + Cross Over Sub 3.960” 4 5,517’ Tieback Seal Assy to No Go Locator 6.180” 5 5,519’ HRD-E ZXP Liner Top Packer SBR 7.390” Lower Completion 6 5,513’ 7” x 9-5/8” SLZXP Liner Top Packer with 11.27’ Tieback Sealbore 6.180” 7 5,750’ Tendeka Water Swell Packer 3.850” 8 13,880’ Shoe 3.970” OPEN HOLE / CEMENT DETAIL Driven 12-1/4" Stg 1 –Lead 514 sx / Tail 400 sx Stg 2 –Lead 553 sx / Tail 269 sx 8-1/2” Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 379’ MD Hole Angle @ XN = 67 ° Hole Angle @ Liner Top = 85° Max Hole Angle = 96° TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API#: 50-029-23682-00-00 Completed by Innovation: 7/19/2020 CASING AND LEAK-OFF FRACTURE TESTS Well Name:MPU I-37 Date:7/7/2020 Csg Size/Wt/Grade: Supervisor:Lott / Montague Csg Setting Depth:5,694 3,815 TVD Mud Weight:8.9 ppg LOT / FIT Press =629 psi LOT / FIT =12.07 ppg Hole Depth =5724 md Fluid Pumped=1.1 Bbls Volume Back =0.9 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here ->00 ->00 ->236 ->10 339 ->4105 ->15 534 ->6195 ->20 692 ->8266 ->25 875 ->10 319 ->30 1063 ->12 398 ->35 1259 ->14 467 ->40 1461 ->16 521 ->45 1670 ->18 573 ->50 1893 ->20 629 ->55 2097 -> ->60 2326 -> ->65 2544 -> ->69 2732 Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0629 ->02732 ->0.5 575 ->12730 ->1555 ->22727 ->2525 ->32726 ->3500 ->42725 ->4484 ->52724 ->5472 ->10 2718 ->6460 ->15 2712 ->7451 ->20 2709 ->8443 ->25 2705 ->9434 ->30 2702 ->10 427 -> -> -> -> -> 9.625 40#/47# L-80 0 2 4 6 8 10 12 14 16 18 20 0 10 15 20 25 30 35 40 45 50 55 60 65 69 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 1020304050607080Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 629 575555525500484472460451443434427 273227302727272627252724 2718 2712 2709 2705 2702 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 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA Activity Date Ops Summary 6/27/2020 Roads and pads cont. to prep and grade dirt work around MP I-37. Install Geo-skid in mud mod. Take down hand rails on wellhouse next to I-37;Set herculite and rig mats around MP I-37. Walk sub base off MP I-09. Install starting head and diverter 'T'. Stage wellhead, tree, MPD behind well. Cont. laying rig mats. Roads and pads continue to prep pad and grade dirtwork for mods. 6/28/2020 Cont. walking sub over I-37. Add dirt and shims multiple times as rig compacts softer dirt and sinks. Sim Ops: Cont. to lay rig mats for remaining mods. Clean up rig mats and herculite around I-09;Continue shimming up and leveli ng sub base. Spot and shim catwalk, pipe shed, mud mod, and gen mod. Switch to high lint at 18:00. Peak Released at 17:00;Set out riggers. Scope up, bridal down. Hook up interconnects. Rig up Air, steam and water. Spot cuttings box and containment. Work on rig acceptance checklist.;Set stack on diverter 'T'. Torque bolts on starter head, DSA, and stack. Install knife valve. Continue N/U diverter system. Sim Ops: C/O saver sub. Move water around pits to ensure no leaks. Prime pumps.;Cont. to N/U Diverter system, Roads and Pads crane install rig mats, twin tower and remaining diverter section. Finish rig acceptance checklist. Re-Torque DSA bolts. Chain off stack. Install riser and air up boots. Install drain hoses to drip pan.;Sim Ops: Perform derrick inspection and grease crown. Install and function test hydraulic elevators. Function test both mud pumpe. Energize Accumulator system. Install short mousehole.;P/U mousehole, RIH and close annular. Drift, pick up, and rack back 10 stands of drill pipe. Rig accepted at 04:30.;Daily fluid hauled to G&I 0 bbls total = 0 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 260 bbls total = 260 bbls Daily fluid lost to formation 0 Total= 0 bbls 6/29/2020 Cont. to drift (3.125"), pick up and rack back 5" NC50 drill pipe.;Service rig: install new die on roughneck. Install roller on spinners.;Cont. to drift (3.125"), pick up and rack back 5" NC50 drill pipe total=100 stands, and 8 stands HWDP (2.75" drift);Service rig: grease crown, top drive, blocks, IBOP.;Pick up Jar stand with 1 joint HWDP and rack back.;Test diverter system on 5" joint of drill pipe. Knife open 7 seconds, bag close 10 seconds. Accumulator drawdown: starting pressure 3000 psi, final 1950 psi. First 200 psi recharge in 20 seconds, full recharge 58 seconds. (6) N2 bottles at 2367 psi average.;Stage UBHO and bottleneck XO on rig floor. M/U Bit to 1.5° bend motor as per Halliburton.;Pre-spud meeting. Flood conductor with water and PT surface lines to 3000 psi - good. RIH tagging up at 42'. Displace to spud mud. Drill from 42' to 220' at 350 gpm, 300 psi, 40 rpms, 1000 ft-lbs, WOB 1-3K. PUW 43K, SOW 43K, ROTW 43K.;CBU while BROOH 1 stand at 350 gpm, 300 psi, 40 rpms, 1000ft-lbs. POOH, pulling 20K over at 155'. Attempt to work through. BROOH to 120' at 350 gpm, 330 psi, 20 rpms, 1200 ft-lbs. POOH on elevators.;Cont. M/U BHA. Check bit - good. M/U DM collar. EWR-M5, TM collar, UBHO. Measure RFO MWD to MTR = 4.91/7.87 = 0.624 = 224.60°. Oreintate UBHO.;Halliburton MWD downloading tool info for upload, with some network issues.;Upload MWD data to tool. Hang sheave for wireline while uploading.;Continue to M/U BHA: (3) Non Mag flex collars. Tag up at 125' (2nd drill collar). Attempt to work though. L/D drill collar. P/U HWDP stand with crossover on bottom. Wash and ream from 118' to 176' at 350 gpm, 480 psi, 20 rpms, 1200 ft-lbs. Rack HWDP stand back. P/U remaining non mag flex;collars (2) and RIH to 220'.;Drill 12-1/4" surface F/ 220' - T/ 469' (249' total, 55 fph AROP). WOB XK, 450 gpm, 810 psi, 60 rpm, 2.5K tq on, 9.43 ppg ECD with 9.0 ppg MW. P/U 62K, S/O62XK, ROT 62K. Kick off at 315' with TF 340°. Conduct Gyro surveys every stand. Pump through bleeder while Gyro to clear flowline.;Screen up shaker screens to 140's.;Distance to WP07 = 0.41', 0.31' High, 0.26' Left.;Daily fluid hauled to G&I 114 bbls total = 114 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 520 bbls total = 780 bbls Daily fluid lost to formation 0 Total= 0 bbls 6/30/2020 Drill 12-1/4" surface F/ 469' - T/ 846' (377' total, 63 fph AROP). WOB 8K, 550 gpm, 1350 psi, 80 rpm, 2.6K tq on, 9.6 ppg ECD with 9.0 ppg MW. P/U 79K, S/O 77K, ROT 76K. Conduct Gyro surveys every stand. Pump through bleeder while Gyro to clear flowline.;Sliding as necessary for 3°/100 build and turn to 600', followed by a short tangent to 850'.;Drill 12-1/4" surface F/ 846' - T/ 1500' (654' total, 109 fph AROP). WOB 6K, 550 gpm, 1540 psi, 80 rpm, 4.5K tq on, 10.1 ppg ECD with 9.0 ppg MW. P/U 87K, S/O 84K, ROT 85K. Last Gyro survey 820' (bit depth 926'), rig down and release gyro. Backream full stands.;slide for 3 -4°/100 build/turn rate.;Drill 12-1/4" surface F/ 1500' - T/ 2074' (574' total, 96 fph AROP). WOB 10K, 550 gpm, 1590 psi, 80 rpm, 3.9K tq on, 9.86 ppg ECD with 9.0 ppg MW. P/U 100K, S/O 87K, ROT 94K. Backream full stands. Slide for 4°/100 build. Base of permafrost logged at 1840'MD.;Drill 12-1/4" surface F/ 2074' - T/ 2772' (698' total, 116 fph AROP). WOB 6-14K, 550 gpm, 1650psi, 80 rpm, 5.5K tq on, 10.37ppg ECD with 9.1ppg MW. P/U 106K, S/O 90K, ROT 97K. Max Gas 335U. Backream full stands. Start tangent section 2378'.;Distance to WP07: 7.51', 4.82' Low, 5.76' Right;Daily fluid hauled to G&I 1026 bbls total = 1140 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 910 bbls total = 1690 bbls Daily fluid lost to formation 0 Total= 0 bbls 6/29/2020Spud Date: Well Name: Field: County/State: MPU I-37 Milne Point Hilcorp Energy Company Composite Report Alaska 50-029-23682-00-00API #: 7/1/2020 Drill 12-1/4" surface F/ 2772' - T/ 3407' (635' total, 106 fph AROP). WOB 9K, 550 gpm, 1740psi, 80 rpm, 7.5K tq on, 9.88 ppg ECD with 9.1ppg MW. P/U 122K, S/O 88K, ROT 104K. Max Gas 567U. Backream full stands. Maintenance slides as needed through tangent. Start 4°/100 turn and build at 3300'.;Drill 12-1/4" surface F/ 3407' - T/ 3978' (571' total, 95 fph AROP). WOB 11K, 550 gpm, 1795psi, 80 rpm, 10.K tq on, 10.03 ppg ECD with 9.2 ppg MW. P/U 140K, S/O 93K, ROT 112K. Max Gas 351U. Backream full stands. Sliding as needed for 4°/100 turn and build.;Drill 12-1/4" surface F/ 3978' - T/ 4500' (522' total, 87 fph AROP). WOB 6K, 550 gpm, 1815psi, 80 rpm, 10.5K tq on, 9.86 ppg ECD with 9.15 ppg MW. P/U 146K, S/O 95K, ROT 116K. Max Gas 991U. Backream full stands. Sliding as needed for 4°/100 turn and build.;Drill 12-1/4" surface F/ 4500' - T/ 4933' (433' total, 72 fph AROP). WOB 6-16K, 550 gpm, 1755 psi, 80 rpm, 12.1K tq on, 9.71 ppg ECD with 9.2 ppg MW. P/U 153K, S/O 92K, ROT 115K. Max Gas 2006U. Backream full stands. Sliding 30-48' as needed for 4°/100 turn and build .;Distance to WP07: 8.06', 5.84' Low, 5.55' Right;Daily fluid hauled to G&I 1211 bbls total = 2351 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 1300 bbls total = 2990 bbls Daily fluid lost to formation 0 Total= 0 bbls 7/2/2020 Drill 12-1/4" surface F/ 4933' - T/ 5378' (445' total, 74 fph AROP). WOB 12K, 550 gpm, 1970 psi, 80 rpm, 14.6K tq on, 10.01 ppg ECD with 9.2 ppg MW. P/U 149K, S/O 88K, ROT 115K. Max Gas 2006U. Backream full stands. Sliding 30-48' as needed for 4°/100 turn and build .;Drill 12-1/4" surface F/ 5378' - T/ casing point at 5704' (326' total, 72 fph AROP). WOB 12K, 550 gpm, 2000 psi, 80 rpm, 13.5K tq on, 10.07 ppg ECD with 9.2 ppg MW. P/U 148K, S/O 87K, ROT 116K. Max Gas 679U. Backream full stands. Obtain final survey on bottom. SB NB sands logged at 5480'MD;Monitor well - static. BROOH from 5704' to 5444' above the NB sands; 550 gpm, 2000 psi, 80 rpms, 11-16Kft-lbs. Max gas 603U. ECD 10.02 pps, 9.0 ppg mud. P/U 148K, S/O 87K, ROT 116K;Circulate hole clean, pump high viscosity sweep (10% increase, on time), and circulate total of 2 x surface-surface at 550 gpm, 1000 psi, 80 rpms, 11-16Kft-lbs. Max gas 452U. Reciprocate pipe. Rack back stand after sweep is out of hole to 5317'.;RIH from 5,317 to 5704' on elevators, 5K drag observed, no fill.;BROOH from 5704' to 3600' at 550 gpm, 1700 psi, 80 rpms, 10Kft-lbs at 35 fpm with no issues. P/U 140K, S/O 92K, ROT 110K.;Continue to BROOH from 3600' to 2010', 550 gpm, 1560 psi, 80 rpm, 5.2Kft-lbs. Max gas 377U at 35 fpm. no issues. PUW 103K, SOW 87K, ROT 89K.;Cont. to BROOH from 2010' to 1883' slowing pulling speed to obtain 2 x BU prior to permafrost (1840') at 550 gpm, 1550 psi, 80 rpms, 5Kft-lbs. ECD 10.34. Max gas 269U.;Cont. to BROOH from 1883' to 738' at 35 fpm, no issues. 550 gpm, 1335 psi, 60 rpms, 1.6Kft-lbs. PUW 77K, SOW 74K, ROT 76K. Max Gas 276U;Distance to WP07: 34.88', 34.29' Low, 6.42' Right;Daily fluid hauled to G&I 1105 bbls total = 3456 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 1040 bbls total = 4030 bbls Daily fluid lost to formation 0 Total= 0 bbls 7/3/2020 Monitor well, static. Rack back 9 stands HWDP and jar stand. L/D BHA: (3) flex collars, UBHO. Plug in and download MWD. Pull pulser from TM. Cont. L/D BHA. Bit grade: PDC 1-2-DL-N-X-1-CT-TD, Roller 1-1-WT-A-E-1-NO-TD;Clean and clear rig floor of BHA components. R/D rig tongs.;R/U to run casing. Remove 5" elevators. M/U Volant tool, bail extensions. Bring handling equipment to rig floor. Install casing elevators. R/U power tongs.;RIH with 9-5/8" casing as per tally to 2,201'. M/U shoe track assembly, install top hat as per Halliburton. Check floats - good. Cont. RIH with 9-5/8", 40#, L-80 TXP casing, installing centralizers as per tally.;Circulate bottoms up staging pumps up to 6 bpm, 160 psi, 10 rpms, 7Kft-lbs, reciprocating pipe. PUW 118K, SOW 88K, ROT 120K.;Continue to RIH with 9-5/8", 40#, L-80 TXP casing to 3,720'. Bakerlok and M/U ES cementer to 3,762'. RIH with 9-5/8" casing crossing over to 9-5/8",47#, L-80 DWC casing from 3,762' to 4,222'. PUW 215K, SOW 106K at 60 fpm.;Power tong make/break pin and housing cracked, causing the tongs to not release from joint. Release power tongs. L/D power tongs and pick up back up set of tongs. CBU while changing out tongs, stagine up to 6 bpm, 245 psi, reciprocating pipe.;Cont to RIH with 9-5/8", 47#, L-80 casing from 4,222' to 5,694' at 60 fpm, slowing to 40 fpm with 5 joints left; crossover to 9-5/8", 47#, L-80, TXP at 4,567; crossover to 9-5/8", 47#, L-80 TCII at 5136'. PUW 245K, SOW 110K. Calculated displacement for casing run 86.7 bbls, Actual 38.8 bbls.;Circulate surface to surface lowering YP to 17. Stage pumps up to 7 bpm, 235 psi, 1-2 rpms with torque limiter set at 14.6Kft-lbs. Reciprocating pipe. PUW 235K, SOW 115K. Sim Ops: R/D power tongs, elevators and bail extensions, blow through cement line. R/U cementers. Prep pits.;Daily fluid hauled to G&I 285 bbls total = 3741 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 520 bbls total = 4550 bbls Daily fluid lost to formation 25 Total= 25 bbls 7/4/2020 PJSM with all parties involved with Cmt Job. Break out of Volant tool and re-engage. Rig up cement line to Volant and break circulation. Perform 1st Stage cmt job: Wet lines w/ 5 bbls H2O. P/T lines 1460 psi low / 4050 psi high (test good). Pump 60 bbls 10# spacer (5# poly flake, 4# red dye in first 10bbls), 5 bpm 341 psi. Drop btm bypass plug. 12ppg 2.349y 13.92gal/sk 515 sks 215 bbls 5 bpm 478 PSI 15.8ppg 1.151y 4.969 gal/sk 400sk 82 bbls 4 bpm 790 PSI. Drop top shutoff plug. HES pump 20 bbls H2O 5bpm 370 psi. Rig disp MP#2 - 245 bbls 9.4 spud mud, 7 bpm, 370 psi icp 6 bpm fcp 870 psi. HES- 80 bbls 9.4 ppg tuned spacer, 5 bpm, 400 psi Rig disp 73 bbls 9.4 spud mud, 6 bpm, 870 psi. Slowed last 13 bbls to 3 bpm, FCP 675psi. Pumped 15 bbls over calculated Displacement. Showed pressure climb from 900 to 1442psi, once shutting down we observed pressure drop off to 150 psi. pumped plug back to 1400 psi shutdown and pressure dropped to 150 psi over a minute or 2. Shutdown and call Engineer. Bled off pressure on standpipe to monitor bleed back to see if floats held. pressure went to zero with no build, unsting volant, fluid in pipe static, backside static. Drop free fall opening plug. Waited 20 minutes for plug to fall. Pump 1/2 bbl see tool shift @ 600 psi. CBU through stage tool bringing 37 bbls green cmt to surface. CBU x 2 @ 5 bpm. Lost 65 bbls during Disp. CIP @ 12:10 Overboard 60 bbls spacer, 37 bbls green cmt, 148 bbls contaminated mud before taking returns back to pits. Shut down and flush stack with Black Water: disconnect knife valve and flush stack while functioning bag x3, repeat process three times. Connect knife valve. Conduct pump efficiency test pump 80 bbls by stroke counter from one pit to another - 80 bbl gain by pit strap. Continue to circulate through stage tool @ 4 bpm, 185 psi while prepping for 2nd stage cmt. No losses. Cont. circulating through ES cementer 200 gpm, 230 psi no losses. Halliburton cementers at Doyon 14. Sim Ops: load and process 5" drill pipe. Pump 2nd stage cement as per detail: HES pump 5 bbls water at 4 bpm, 200 psi Pump 60 bbls 10 ppg spacer (5# poly flake, 4# red dye in first 10bbls), 4 bpm, 165 psi 290 bbls 10.7 ppg ArcticCem Lead cmt (2.944 yld, 553 sxs), 5 bpm, 465 psi. Observe good 10.65 ppg green cement back 265 bbls into lead. Pump 56 bbls 15.8 Class G tail cement (1.160 yld, 270 sxs) at 4 bpm, 470 psi. Drop closing plug HES pump 20 bbls water at 5 bpm, 310 psi. Rig displaced with 122 bbls (123 calculated) 9.4 ppg spud mud at 7 bpm, 792 psi. Slow rate to 3 bpm with 13 bbls to go. FCP 563 psi, bump plug and pressure up to 1870 psi, observing tool shift close at 1700 psi. Hold pressure for 5 minutes and bleed back 1 bbl to confirm tool closed. CIP at 02:32, no losses. 224 bbls green cement returned to surface. R/D cement line, and connect to bleeder. Flush out line with black water. De-energize accumulator and disconnect knife valve. Fill stack and flush with black water functioning bag x3, repeat process x3. Blow down black water, hole fill, and cement lines. Sim Ops: break apart diverter sections. Hook up bridge cranes and disconnect chain binders from stack. Break and 4-bolt from speed head to stack. Set 'E' slips as per NOS with 115K on slips. Rig up and prep to cut casing. Sim Ops: break out and L/D Volant tool. Vac out cut joint. Off load mud and flush black water through pits. Daily fluid hauled to G&I 762 bbls total = 4503 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from A Pad Lake 700 bbls total = 5250 bbls Daily fluid lost to formation 87 Total= 112 bbls 7/5/2020 Cut excess casing and L/D cut joint = 29.21' cut. Remove casing elevators, install 5" elevators. Set stack back down and hot bolt. Air up riser boots. Pick up stack washing tool, and wash stack. Sim Ops: continue offloading spud mud.;N/D diverter system. Pull master bushings and remove riser. Remove knife valve. Clean out flow box. N/D diverter 'T', DSA, and speed head. Disassembly vent line. Sim Ops: continue cleaning pits. clear rig floor of riser, casing handling equipment, and master bushings.;Dress off casing cut. N/U wellhead and test void 500/3800 psi (80% casing burst 47#). Set test plug in wellhead.;Install DSA and spacer spool. Pick up MPD RCD with blocks and pick up. N/U BOP stack and chain off. Lower RCD and install. Sim Ops: continue cleaning pits. C/O bearings on drag chain.;Cont. tightening flange bolts. Install MPD hard lines. Remove bridge cranes. Hook up choke and kill lines. Center stack and bring split bushings and riser to rig floor. Obtain RKB measurements. Install mouse hole.;Flood stack, MPD hard lines and choke. Test MPD lines 250/1400 psi good. Pull MPD test cap and install riser.;Finish installing riser. Chain off stack. Install split bushings and hydraulic elevators. M/U 5" test joint with TIW, Dart valve. Flood lines, purge air. Attempt a body test on BOPE - trouble shoot leak. Mezzanine kill valve leaking.;Test BOPE's 250/3000 psi on 5" and 3-1/2" test joints. Test gas alarms, flow paddle, pit G/L. AOGCC right to witness waived by Jeff Jones. SimOps: rebuild Mezzanine Kill valve.;Daily fluid hauled to G&I 1580 bbls total = 6083 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from L Pad Lake 520 bbls total = 5770 bbls Daily fluid lost to formation 0 Total= 112 bbls 7/6/2020 Cont to test BOPE 250/3000 psi on 5" and 3.5" test joints. AOGCC right to witness waived by Jeff Jones. HCR choke F/P - greased and re-tested. Accumulator drawdown: starting pressure 3000 psi, final 1650 psi. First 200 psi recharge 16 seconds, full recharge 76 seconds.(6) N2 bottles at 2750 psi ave;R/D testing equipment. Pull test plug, B/D test joint, pump in sub and TIW. Blow down choke and kill lines. Install wear bushing;M/U drill out BHA, M/U 8.5" bit to motor with 1.5° bend, float sub. RIH with HWDP and Jars to 594' from derrick. Pick up, drift and single in hole to 913'.;Cont. to pick up, drift (3.125") and single in hole with 5" drill pipe from 913' to 1836'. PUW 88K, SOW 77K.;Fill pipe and wash down from 1836', tag ES cementer at 1951', on depth. Drill out ES cementer with WOB 5-12K, 50 rpms, 4.5Kft-lbs, 350 gpm, 615 psi. Work though multiple times with and w/o pumps and rotary with no issues.;Cont. to pick up, drift (3.125") and single in the hole with drill out assembly to 5,049'. RIH with drill pipe from derrick from 5,049' to 5,174'. Set 8K down. Establish circulation. Wash and ream down to 5,234.;Cont to RIH on elevators from 5,234' to 5,537' washing last stand down. PUW 170K, SOW 87K, ROT 110K;Circulate hole clean 1.5x BU reciprocating pipe at 500 gpm, 995 psi, 20 rpms, 13Kft-lbs. Rack back stand to 5,490';R/U and PT casing to 2500 psi for 30 minutes - good test. Pumped 4.2 bbls, bled back 4.2 bbls. Blow down choke and kill lines.;Wash down from 5,490' tagging up at 5,558'. Drill cement, shoe track and 20' of new hole to 5724'; 350 gpm, 794 psi, 30 rpms, 13Kft-lbs, WOB 5- 10K. ROP~125 fph with 10K while drilling cement. Tag up on baffle adapter at 5,576', FC at 5,611', Shoe at 5,696'. PUW 157K, SOW 72K, ROT 110K.;Start to displace to displace to Baradril-N drilling mud.;Continue displacing to 8.9 ppg Baradril-N drilling fluid at 450 gpm/ 888 psi, 30rpm, 11Kft-lbs Continue circulating to ensure even mud wt in and out. Monitor well, static. PU 158, SO 73, ROT 107K;Rig up, flush lines and attempt to perform FIT to 12.0 ppg, leaked off at 11.6 - observe aerated mud in pits. possible lost prime on pumps. Rig down.;Circulate bottoms up, treating mud with De-foam at 350 gpm, 550 psi. Clean out suction screens.;Rig up, flush lines and perform FIT to 12.0 ppg EMW with 8.9 ppg drilling fluid; 629 psi. Rig down and blow down lines. Monitor well, static.;POOH from 5,675' to 5350', no indication of swabbing. Pump dry job, blow down lines. Continue to POOH to 4,656'.;Daily fluid hauled to G&I 228 bbls total = 6311 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from A Pad Lake 260 bbls total = 6030 bbls Daily fluid lost to production formation 0 Total= 0 bbls Fluid lost on surface hole = 112 bbls y 400sk 82 bbls 290 bbls 10.7 ppg ArcticCem Lead cmt (2.944 yld, 553 sxs), 5 bpm, 465 psi. Observe good 10.65 ppg green cement back 265 bbls into lead. g(y) Pump 56 bbls 15.8 Class G tail cement (1.160 yld, 270 sxs) at 4 bpm, 470 psi. g( g k 515 sks 215 bbls 7/7/2020 Continue to POOH an elevators from 4556' to 540'. L/D 17 jt HWDP and jars. Break off and L/D Bit, Float Sub and Mtr Assy. Bit Graded:1-1-WT-A-E-I-NO- BHA;Clean and clear Rig floor. Stage BHA components on rig floor.;PJSM. P/U M/U Bit, Bit Sleeve, Geo Pilot, ADR, Inline Stab, DGR, PWD, DM, TM and Float Sub as per Sperry Reps. Plug in and Up Load tools.;PJSM Cont down load MWD. P/U M/U 6.75" NM FC, Float Sub (NonPorted), 2 ea 5" HWDP, 6.5" SLB Hydra Jars and 5" HWDP BHA Length 280.5'.;PJSM Single in BHA 3 W/ 5" NC-50 19.5# S-135 D.P. F/ Skate F/ 208' to 5,646' MD. Pass through ES at 1,951' MD, no issue. (Drift 3.125" OD) Break in Geo Pilot at 2,500' MD. P/U 148K SLK 90K.;PJSM Cut and slip drilling line. Cut 87' (14 wraps) Accum 39105 TM. 475' left on spool. Check brakes. TRQ Deadman 80 ft/lbs. SIMOPS CBU 2X 300 GPM, 530 PSI, 9.38 ECD Max Gas 9U.;PJSM Service rig. Grease & inspect Crown, Top Drive & Iron Roughneck. Check oil on TD. Inspect welds on carriage.;PJSM Monitor well 10 min, static. M/U stand, pull bushings, remove riser. M/U MPD Bearing to stand and install to RCD. M/U Clamp and break Circ through MPD Equip as per Beyond rep onsite. 1 bpm 155 PSI.;PJSM Wash down F/ 5,646' to Shoe at 5,724'' MD. 350 GPM, 1,030 PSI, 80 RPM, TRQ 10.5K, ECD 9.75. P/U 145K SLK 75K ROT 100K.;SPR @ 5694' (3,815' TVD) W/ 8.9 ppg MW MP #1 32-190, 48-235 MP #2 32-190, 48-235;Drill 8.5" Injection Hole F/ 5,724' to 6,400' MD (3,799' TVD) Total 676’ (AROP 112.6’) 500 GPM/ MPD 494, 1,365 PSI, 70-100 RPM, TRQ on 10K, TRQ off 13K, WOB 6-16K. P/U 162K, SLK 67K, ROT 100K. Max Gas 1,091U. MPD full open.. Maintain ~90° Inc 0.8° Azi as per Geo.;Back ream 30'. Adjust RPM's due to pipe wobble at surface.;Distance to WP #7: 23.02', 21.75' Low, 7.54' Right 1 fault crossed so far this lateral, 5,775' MD 10' DTS 3 concretions drilled for a total 6’ (1.0% of the lateral) Max Gas 1,091U;Daily fluid hauled to G&I 611 bbls total = 6,922 bbls Daily metal recovered 0 lbs, total = 0 lbs Daily water hauled from A Pad Lake 130 bbls total = 6,160 bbls Daily fluid lost to production formation 0 Total= 0 bbls Fluid lost on surface hole = 112 bbls 7/8/2020 Drill 8.5" Injection Hole F/ 6,400' to 7,086' MD (3,816' TVD) Total 686’ (AROP 114.3’) 500 GPM/ MPD 494, 1,585 PSI, 70-100 RPM, TRQ on 10K, TRQ off 13K, WOB 6-20K. ECD 10.9. P/U 161K, SLK 59K, ROT 100K. Max Gas 1,504U. MPD full open.. Maintain ~90° Inc 0.8° Azi as per Geo.;Fault #3 at 6,221' MD 57' DTN steered down through the Ugnu MF-Clays, NA-Sand and NA-Clays out of zone. Fault #4 at 6,980' MD 5' DTN Cont steer down back in NB Sand 7,200' MD total 979' out.;Back ream 30'. Adjust RPM's due to pipe wobble at surface. SPR 6,766' MD (3,802' TVD) MW 8.9 MP #1 32-239, 48-285 MP #2 32- 238, 48-293.;Drill 8.5" Injection Hole F/ 7,086' to 7,594' MD (3,830' TVD) Total 508’ (AROP 84.7’) 500 GPM/ MPD 494, 1,680 PSI, 70-100 RPM, TRQ on 13K, TRQ off 14K, WOB 10-16K. ECD 10.87. P/U 182K, SLK 35K, ROT 100K. Max Gas 910U. MPD full open.. Lost SLK at 7,594' MD.;Fault #5 at 7,430' MD 17' DTN from near NB-Sand bottom to top NB-Sand. Drilled in NB-Sand until 7,684’ MD drilled out top of NB-Sand. Out of zone for 58’.;Back ream 30'. Adjust RPM's due to pipe wobble at surface. SPR 7,594' MD (3,830' TVD) MW 8.9 MP #1 32-325, 48-380 MP #2 32-325, 48-380.;Drill 8.5" Injection Hole F/ 7,594' to 8,358' MD (3,837' TVD) Total 764’ (AROP 127.3’) 500 GPM/ MPD 485, 1,740 PSI, 70-100 RPM, TRQ on 17K, TRQ off 16K, WOB 3-8K. ECD 11.03. P/U 185K, SLK 48K, ROT 97K. Max Gas 1,434U. MPD full open.;Fault #6 at 7,742’ MD 15' DTS. just above the NB-Sand down into NB- Sand base. Control drill at 7,910' MD for a BU to control hole loading up and ECD. Back ream 30'. Adjust RPM's due to pipe wobble at surface.;SPR 8,231' MD (3,833' TVD) MW 8.9 MP #1 32-345, 48-400 MP #2 32-345, 48-400.;Drill 8.5" Injection Hole F/ 8,358'' to 8,900' MD (3,856' TVD) Total 542’ (AROP 90.3') 500 GPM/ MPD 500, 1,885 PSI, 70-100 RPM, TRQ on 17K, TRQ off 15K, WOB 6-16K. ECD 11.18. P/U 174K, SLK 35K, ROT 98K. Max Gas 1,412U. MPD full open.;Went out top NB Sand at 8,691' MD into NA Clay Control drill at 8,358' MD for a BU to control hole loading up and ECD. Back ream 30'. Adjust RPM's due to pipe wobble at surface.;SPR 8,741' MD (3,844' TVD) MW 9.1 MP #1 32-370, 48-435 MP #2 32-370, 48-430.;Distance to WP #7: 19.85', 18.76' Low, 6.49' Right 5 fault crossed so far this lateral. 20 concretions drilled for a total 76’ (2.4% of the lateral) Footage NB Sand=1,960' Out NB Sand 1,171' Total 3,131'.;Daily fluid hauled to G&I 513 bbls total = 7,435 bbls Daily metal recovered 25 lbs, total = 25 lbs Daily water hauled from A Pad Lake 520 bbls total = 6,680 bblsDaily fluid lost to production formation 0 Total= 0 bbls Fluid lost on surface hole = 112 bbls 7/9/2020 Drill 8.5" Injection Hole F/ 8900' to 9,509' MD (3,894' TVD) Total 609’ (AROP 101.5') 525 GPM/ MPD 512, 1,970 PSI, 70-100 RPM, TRQ on 14K, TRQ off 15K, WOB 6-12K. ECD 11.32. P/U 155K, SLK 64K, ROT 97K. Max Gas 816. MPD full open..Back Ream Full Stands.;J-26 close approach 95.22' at 8846' MD. Control drill at 150 fph from 9121’ to 9282’ and obtain Btms Up x2. ECD down from 11.4 to 11.1 Increase lube concentration from 1.5% to 2.5%. Regained SO Wt, lost 3K TQ and lost pipe wobble.;Drill 8.5" Injection Hole F/ 9509' to 9,608' MD (3,899' TVD) Total 609’ (AROP 101.5') 525 GPM/ MPD 505, 1,990 PSI, 120 RPM, TRQ on 14.5K, TRQ off 14K, WOB 6-12K. ECD 11.32. P/U 156K, SLK 65K, ROT 97K. Max Gas 578. MPD full open..Back Ream Full Stands.;Rack Back 1 stand. Circulate and condition hole while Geo's reconfigure plan for J-25 close approach.;Drill 8.5" Injection Hole F/9608' to 10,076' MD (3,899' TVD) Total 468’ (AROP 104') 525 GPM/ MPD 508, 2,120 PSI, 120 RPM, TRQ on 16K, TRQ off 16.5K, WOB 10-16K. ECD 11.26. P/U 176K, SLK 58K, ROT 100K. Max Gas 1,569U. MPD full open..Back Ream Full Stands.;SPR at 10,076' (3,899' TVD) MW 9.05 MP #1 32-330, 48-395 MP #2 32-330, 48-395;Drill 8.5" Injection Hole F/10,076' to 10,728' MD (3,916' TVD) Total 652’ (AROP 108.7') 500 GPM/ MPD 482, 1,990 PSI, 100 RPM, TRQ on 14.5K, TRQ off 13K, WOB 5-15K. ECD 11.35. P/U 144K, SLK 58K, ROT 98K. Max Gas 1,438U. MPD full open..Back Ream Full Stands.;Begin dropping angle at 10073' from 91° to 88° to steer under J-25. At 10,582' MD turn pumps down go to 100% deflection to get the assembly to build. Exiting the NB-Sand base at 10,638’ MD. Building inclination 91° to get back in sand.;Drill 8.5" Injection Hole F/10,728' to 11,155' MD (3,917' TVD) Total 427’ (AROP 71.2') 500 GPM/ MPD 482, 2,165 PSI, 100- RPM, TRQ on 15.5K, TRQ off 14K, WOB 6-18K. ECD 11.64. P/U 143K, SLK 48K, ROT 97K. Max Gas 1,157U. MPD full open..Back Ream Full Stands.;3X BU due to ECD F/10,995' to 11,095' MD F/ 11.95 to 11.62 Crossed J-25 at 11,002' MD CC 34.86' no issues. Cont 91° build to reenter NB Sand. Had an inverter fault on MP'S had to reset.;SPR at 11,037' (3,922' TVD) MW 9.05 MP #1 32-460, 48-540 MP #2 32-460, 48-450;Distance to WP #7: 42.23', 42.22' Low, 0.90' Right 5 fault crossed so far this lateral. 24 concretions drilled for a total 84’ (1.5% of the lateral). Footage NB Sand=3,678' Out NB Sand 1,742';Daily fluid hauled to G&I 684 bbls total = 8,119 bbls Daily metal recovered 3 lbs, total = 28 lbs Daily water hauled from A Pad Lake 780 bbls total = 7,460 bbls Daily fluid lost to production formation 0 Total= 0 bbls Fluid lost on surface hole = 112 bbls 7/10/2020 Drill 8.5" Injection Hole F/11,155' to 11,666' MD (3,909' TVD) Total 511’ (AROP 85') 500 GPM/ MPD 470, 1885PSI, 120- RPM, TRQ on 15.K, TRQ off 14K, WOB 12-16K. ECD 11.25. P/U 158K, SLK 45K, ROT 100K. Max Gas 1,485U. MPD full open..Back Ream Full Stands. Dump and dilute 200 bbls for MBT;Thought to have reentered NB Sand base at about 11,120’ MD. At ~11,450 MD started seeing dynamic losses about 8-10 bph W/ slight breathing at connection. Exited the sand top at 11,569’ MD. Lost 20 bbl for tour.;Drill 8.5" Injection Hole F/11,666' to 11,984' MD (3,924' TVD) Total 318’ (AROP 53') 500 GPM/ MPD 475, 2,220 PSI, 80-120- RPM, TRQ on 16K, TRQ off 15K, WOB 15-18K. ECD 11.56. P/U 158K, SLK 48K, ROT 98K. Max Gas 236U. MPD full open. Back Ream Full Stands.;Unsure if in NA and NB sands. Decision was made to drill down got back in the sand at 11,953’ MD still unsure if NB or NC sand.;Cont seeing dynamic loss rate 8-10 bph W/ ballooning back 5-10 bbls on connections. SPR at 11,984' (3,924' TVD) MW 9.1 MP #1 32-450, 48-540 MP #2 32-440, 48-420;Drill 8.5" Injection Hole F/11,984' to 12,302' MD (3,934' TVD) Total 318’ (AROP 53') 500 GPM/ MPD 478, 2,140 PSI, 100-120- RPM, TRQ on 17K, TRQ off 16K, WOB 6-18K. ECD 11.70. P/U 164K, SLK 35K, ROT 95K. Max Gas 564U. MPD full open. Back Ream Full Stands. Lost SLK @ 12,111' MD.;Tough to drop inc due to a hard streak near the sand top. Currently targeting 84°. The probability of a sidetrack at about 11,240’ MD is high. Cont seeing dynamic loss rate 8-10 bph W/ ballooning back 5-10 bbls on connections. Lost 100 bbl for tour.;Drill 8.5" Injection Hole F/12,302' to 12,747' MD (3,984' TVD) Total 445’ (AROP 74.2') 500 GPM/ MPD 470, 2,226 PSI, 100-120- RPM, TRQ on 16K, TRQ off 15K, WOB 12K. ECD 11.69. P/U 148K, SLK 35K, ROT 98K. Max Gas 1399U. MPD full open.Back Ream Full Stands.;Survey at 12,102’ MD severe right hand walk azi swing 16.72° to 20.73° (8.64° over planned azi of 12.09°) 100% @ 75L toolface maintain a inc of 84° as per Geo, turn the azi back to plan. Assy yield 2.8 – 3.0° doglegs with 100% deflection. Dynamic loss 8-10 bph, ballooning at connections, lost 40 bbl;Projections back to plan at ~12,440’ MD with a max distance to plan of 54’. Turning wellbore to ~9° Azi and holding would put us converging back to plan at ~13,500’ MD. Entered lower sand at ~12,558 MD Cont ahead and confirmed to be NC Sand. Turn up to reenter NB Sand.;Distance to WP #7: 74.73', 55.40' Low, 50.15' Right 5 fault crossed so far this lateral. 35 concretions drilled for a total 261’ (3.7% of the lateral) Footage NB Sand=4,567' Out NB Sand 2,420';Daily fluid hauled to G&I 1,023 bbls total = 9,142 bbls Daily metal recovered 0 lbs, total = 28 lbs Daily water hauled from A Pad Lake 1,040 bbls total = 8,680 bbls Daily fluid lost to production formation 120 Total= 120 bbls Fluid lost on surface hole = 112 bbls 7/11/2020 Drill 8.5" Injection Hole F/12,747' to 12,809' MD (3,988' TVD) Total 62’ (AROP 124') 500 GPM/ MPD 467, 2,220 PSI, 100-120 RPM, TRQ on 16.5K, TRQ off 15.5K, WOB 14K. ECD 11.80. P/U 148K, SLK 35K, ROT 98K. Max Gas 440U. MPD full open. Back Ream Full Stands. Decision was made to OHST to 11,240' MD. Distance to WP 07: 83.79, 74.85' Low 37.52' Right PJSM BROOH F/ 12,809' to 11,158 MD 400-500 GPM/ MPD 379, 1,560 PSI, 100 RPM, TRQ 13K, Max Gas 733U. P/U 155K SLK 45K ROT 100K. Back ream speed 35 ft/min as hole dictates. Losses occurred ~11,412' MD slowed to 400 GPM/ MPD 379. Lost 64 bbls. Lost 104 bbls for tour PJSM Wash down F/ 11,158' to 11,240' MD. Started side track operations at 11,240' to 11,281' (3,915' TVD) 470 GPM, MPD 433, 1,830 PSI, 100 RPM, TRQ 15K, TRQ off 14.5K, WOB 2K. Max Gas 77U. ECD 10.9. P/U 158K SLK 45 ROT 100K. Started troughing at 30 ft/hr F/11240' to 11281' MD.. Drop in ABI F 91.55° to 89.60° F/ original leg at 11281' MD at the end of the first pass W/ 2° difference in inc F/ original well to sidetrack well, 11281' P/U ran in W/ pump but no rotary, and again with no issue. Drill 8.5" Injection Hole F/11,281' to 11,602' MD (3,926' TVD) Total 321’ (AROP 80.3') 400-500 GPM/ MPD 440, 1,906 PSI, 100 RPM, TRQ on 12-16K, TRQ off 13K, WOB 8-12K. ECD 11.2. P/U 154K, SLK 35K, ROT 97K. Max Gas 1,190U. MPD full open. Back Ream full Stands. Lost SLK @ 11,602' MD F/ 11,281' to 11345'Increase ROP and TF to 70L in stages and the deflection F/ 100% to 80% drilled. Increasing ROP 25 ft/hr to 100 ft /hr. Close approach MPJ-09, closest approach 94.55' @ 11,412' MD. Encountering Dynamic losses 10-30 bph adjusting flow rate and ROP. Increase Calcium Carbonate F/ 11 to 15 ppg. Seeing ballooning at connection, 10-12 bbls. Drill 8.5" Injection Hole F/11,602' to 12,302' MD (3,938' TVD) Total 700’ (AROP 116.7') 450-490 GPM/ MPD 463, 1,895 PSI, 100 RPM, TRQ on 8-13K, TRQ off 16K, WOB 8-13K. ECD 11.37. P/U 158K, SLK 35K, ROT 100K. Max Gas 1,150U. MPD full open. Back Ream full Stands. Lost 156 bbls for tour Encountering Dynamic losses ~30 bph adjusting flow rate 475 GPM and 175 ROP. 8% decrease return flow. At ~12,035' MD increased 490 GPM/ MPD 460 dynamic loss rate ~10-15 bph. Cont to see ballooning at connections 10-12 bbl. SPR at 12,048 (3,931' TVD) MW 9.05. MP #1 32-470, 48-595. MP #2 32-455, 48-560 Drill 8.5" Injection Hole F/12,302' to 12,747' MD (3,950' TVD) Total 445’ (AROP 74.2') 500 GPM/ MPD 463, 2,153 PSI, 100 RPM, TRQ on 16.5K, TRQ off 16K, WOB 8-14K. ECD 11.32. P/U 162K, SLK 35K, ROT 98K. Max Gas 1,160U. MPD full open. Back Ream full Stands. Lost 65 bbls Holding 88.5° Inc 11.5° Az as per Geo. Cont to see dynamic loss rate ~12-15 bph. See ballooning at connections 10-12 bbl. SPR at 12,609 (3,945' TVD) MW 9.05. MP #1 32-387, 48-455. MP #2 32-391, 48- 472 Distance to WP #7: 36.50', 35.56' Low, 8.25' Right. PB1 11,240' MD length 1,569'. 5 fault crossed so far this lateral. 30 concretions drilled for a total 127 (1.8% of the lateral) Footage NB Sand=5,288' Out NB Sand 1,748' Daily fluid hauled to G&I 570 bbls total = 9,712 bbls Daily metal recovered 7 lbs, total = 35 lbs Daily water hauled from A Pad Lake 1,040 bbls total = 9,720 bbls Daily fluid lost to production formation 260 Total= 380 bbls Fluid lost on surface hole = 112 bbls 7/12/2020 Drill 8.5" Injection Hole F/12,747' to 13,320' MD (3,962' TVD) Total 573’ (AROP 95.5') 500 GPM/ MPD 472, 2,130 PSI, 100 RPM, TRQ on 17K, TRQ off 15.5K, WOB 12K. ECD 11.23. P/U 161K, SLK 35K, ROT 98K. Max Gas 473U. MPD full open. Back Ream full Stands. Lost 40 bbls;Dynamic loss rate 6-7 bph, ballooning 10-12 bbl on connections. SPR at 13,302' (3,966' TVD) MW 9.05. MP #1 32-328, 48-409. MP #2 32-338, 48-428;Drill 8.5" Injection Hole F/13,320' to 13,892' MD (3,964' TVD) Total 572’ (AROP 95.3') 500 GPM/ MPD 463, 2,095 PSI, 100 RPM, TRQ on 20K, TRQ off 17.5K, WOB 10-15K. ECD 11.6. P/U 169K, SLK 35K, ROT 100K. Max Gas 1,222U. MPD full open. Back Ream full Stands.;Drill 8.5" Injection Hole F/13,892' to 14,233' MD (3,971' TVD) Total 341’ (AROP 56.8') 500 GPM/ MPD 467, 2,140 PSI, 80-100 RPM, TRQ on 21K, TRQ off 16K, WOB 16-18K. ECD 11.54. P/U 164K, SLK 35K, ROT 99K. Max Gas 834U. MPD full open. Back Ream full Stands. Lost 131 bbls for tour;Drill 87.5° as per Geo. Drill to 14,185' MD Geopilot ABIs indicated substantial dogleg 16°DLS over 8.3' F/14170' to 14178' MD. Pull up to 14,170' MD Geopilot 0% deflection, control drill 10' fph knock down DLS. ABIs after dog leg indicated a DLS of 0° over the 8' interval. Resume drilling.;At 14,227' MD concretion deflection indicate 10.6° DLS over 10' F/ 14,216' to 14,226' MD. Ream dogleg reduced to 8.4° DLS over same 10' interval. Drilled encountering multiple concretions to 14,271' MD, Pushed BHA down to 85.55° inc. Geo wanted brought up to >88.5°.Back;Back Ream 2x to message dogleg. ABI through dogleg after reaming which showed a 8.3° DLS over the deflection interval. Noted dog leg and did not want to try and perform small side track to correct. Cont drilling ahead.;Dynamic loss 10-12 bph, with ballooning 10-12 bbl at connections. SPR at 14,109' (3,961' TVD) MW 9.05. MP #1 32-360, 48-440 MP #2 32-355, 48-435;Drill 8.5" Injection Hole F/14,233' to 14,655 MD (3,992' TVD) Total 422’ (AROP 70.3') 500 GPM/ MPD 470, 2,100 PSI, 100 RPM, TRQ on 16K, TRQ off 10K, WOB 10K. ECD 11.37. P/U 157K, SLK 35K, ROT 100K. Max Gas 470U. MPD full open. Back Ream full Stands. Lost 24 bbls;Possible fault at 14,283’ MD. The logs look like NA-Sand, but also poor NB-Sand. Geo dropped to 86° inc to verify sand..;Cont to see dynamic loss rate 4 bph. See ballooning at connections 7-9 bbl. SPR at 14,587 (3,989' TVD) MW 9.05 MP #1 32-370, 48-445 MP #2 32-366, 48-452;Distance to WP #7: 32.72', 31.85' Low, 7.50' Left PB1 11,240' MD length 1,569' 6 maybe 7 fault crossed so far this lateral. 43 concretions drilled for a total 195' (2.2% of the lateral) Footage NB Sand=6,841' Out NB Sand 2,054';Daily fluid hauled to G&I 969 bbls total = 10,681 bbls Daily metal recovered 3 lbs, total = 38 lbs Daily water hauled from A Pad Lake 1,300 bbls total = 11,020 bbls Daily fluid lost to production formation 236 Total= 616 bbls Fluid lost on surface hole = 112 bbls 7/13/2020 Drill 8.5" Injection Hole F/14,655' to 15,227 MD (4,026' TVD) Total 572’ (AROP 95.3') 500 GPM/ MPD 474, 2,220 PSI, 100 RPM, TRQ on 18K, TRQ off 17K, WOB 10-16K. ECD 11.77. P/U 162K, SLK 35K, ROT 99K. Max Gas 612U. MPD full open. Back Ream full Stands. Lost 21 bbls Cont to see dynamic loss rate 5 bph. See ballooning at connections 7-9 bbl. SPR at 15,097' (4,024' TVD) MW 9.05. MP #1 32-422, 48-500. MP #2 32-418, 48-500 Drill 8.5" Injection Hole F/15,227' to TD 15,797' MD (4,000' TVD) Total 571’ (AROP 95.1') 500 GPM/ MPD 454, 2,320 PSI, 90-100 RPM, TRQ on 19.5K, TRQ off 17K, WOB 17-19K. ECD 12.06. P/U 176K, SLK 35K, ROT 99K. Max Gas 1,550U. MPD full open. Back Ream full Stands. 15,288' build to 93.5° using 100% deflection 40L toolface. Yielded average 2.64° dogleg in the sand. Closest approach to MPJ-08 at 14,881' MD 60.96' CC. Perform final survey 15,797' MD 95.7° inc 12.62° Az. Cont to see dynamic loss rate 7-10 bph. See ballooning at connections 10-13 bbl. PJSM Rot & Rec 15,797' to 15,736' MD. Pump Tandem Sweeps 50 bbl 36 Vis 8.7 ppg, 40 bbl 263 Vis 10.2 ppg. 500 GPM/ MPD 469, 2,240 PSI, 100 RPM, TRQ 17K, ECD 11.95. P/U 176K, SLK 35K, ROT 100K. Max Gas 612U. MPD full open. Back Ream full Stands. Sweeps back 30 bbls late, increase 20%. Monitor well close MPD 5 min 112 PSI, Open for 7 min MPD 5 gpm, Close MPD 3 min 38 PSI bleed to 5 gpm, close MPD 3 min 28 PSI build. Bled back 21.3 total. Dynamic loss 10-15 bph, flow back 12-15 bbl. SPR at 15,797 (4,000' TVD) MW 9.05. MP #1 32-440, 48-525. MP #2 32-430, 48-515 PJSM BROOH F/ 15,736' to 15,545' MD CBU 1X per stand for 3 stands. 500 GPM/ MPD 461, 2,280 PSI, 100 RPM, TRQ 18K, ECD 11.89. P/U 176K, SLK 35K, ROT 100K. Max Gas 235U. MPD full open. Back Ream full Stands. Dynamic loss 10-15 bph, flow back 12-15 bbl. Lost 84 bbls for tour PJSM Wash down F/ 15,545' to 15,797' MD 500 GPM/ MPD 461, 2,274 PSI, 100 RPM, TRQ 17K, ECD 11.74. P/U 165K, SLK 35K, ROT 96K. Max Gas 60U. MPD full open. Back Ream full Stands. Dynamic loss 3 bph, flow back 12-15 bbl at connections. PJSM Displace well F/ 9.2 ppg Baradril to 9.2 ppg Quickdril Pump 3X 40 bbl SAPP train followed by 9.2 ppg Quickdril taking returns outside. 377 GPM/ MPD 358, ICP 1,610 PSI FCP 1,150, 100 RPM, TRQ 22-23K, IN ECD 11.44 Fn ECD 10.78. P/U 172K, SLK 35K, ROT 101K. Max Gas 221U. MPD full open. No losses SAPP train back as Calc. Monitor well for 10 min, flow out 3.78 gpm. 8 bbls back. Shut in MPD 3 min 24 PSI, bleed shut in 3 min 22 PSI. Bled, static. SPR at 15,797 (4,000' TVD) MW 9.2. MP #1 32-295, 48-364. MP #2 32-293, 48-365 PJSM PJSM Rot & Rec 15,797' to 15,736' MD. 400- 500 GPM/ MPD 381/ 480, ICP 1,252 FCP 1,732 PSI, 100 RPM, TRQ 17-18K, ECD 11.17. P/U 198K, SLK 35K, ROT 102K. Max Gas 230U. MPD full open. Clean Pits 3 & 4. Build 9.2 ppg Quickdril for back reaming. Dynamic loss 7-9 bph PJSM BROOH F/ 15,797' to 15,664' MD 500 GPM/ MPD 480, ,1,792 PSI, 100 RPM, TRQ 20K, ECD 11.22. P/U 198K, SLK 35K, ROT 102K. Max Gas 249U. MPD full open. Back Ream full Stands. Drop 2.38" OD Drift. Dynamic loss7-9 bph, Distance to WP #7: 27.28', 26.24' High, 7.46' Left. PB1 11,240' MD length 1,569'. 6 fault crossed so far this lateral. 45 concretions drilled for a total 206' (2.0% of the lateral) Footage NB Sand=7,623' Out NB Sand 2,480' Daily fluid hauled to G&I 1,217 bbls total = 11,898 bbls Daily metal recovered 0 lbs, total = 40 lbs Daily water hauled from A Pad Lake 910 bbls total = 11,930 bbls Daily fluid lost to production formation 138 Total= 754 bbls Fluid lost on surface hole = 112 bbls 7/14/2020 PJSM BROOH F/ 15,664' to 13,765' MD. Flow In/Out 500/478 gpm, 1,800 PSI, 100 RPM, TRQ 17-18K, ECD 11.33. P/U 188K, SLK 35K, ROT 98K. Max Gas 518U. MPD full open. Ream at 25-35 ft/min as hole dictates. Slight pack off @ 15,520' & 14,025' MD. Loss 36 bbls Dynamic loss 5-10 bph,;PJSM BROOH F/ 13,765' to 11,412' MD. Flow In/Out 500/442 gpm, 1,800 PSI, 100 RPM, TRQ 17-18K, ECD 10.7. P/U 162K, SLK 35K, ROT 95K. Max Gas 158U. MPD full open. Ream at 30-40 ft/min as hole dictates. Dynamic loss 5-10 bph, MP #1 Pop Off was rebuilt.;PJSM BROOH F/ 11,412' to 10,903' MD. Flow In/Out 350/338 gpm, 990 PSI, 90-100 RPM, TRQ 17.5K, ECD 10.55. P/U 155K, SLK 35K, ROT 95K. Max Gas 1,477U. MPD full open. Dynamic loss 5-10 bph,;AT 11,190’ to 11,150’ Pumped away 50 bbls, 300 bph dynamic loss. Slowed pumps F/ 450 GPM to 250 GPM 890 PSI. MPD dropping to 55 GPM 80% loss in returns, worked stand at reduced rate. Well balloon back 24 bbls while establishing returns. Made hook at 11,083’ MD. Flow In/Out 250/212 gpm, 645 PSI;pull speed 0.5 ft/min. Hole unloaded at BU Max Gas 1,065U Density out 9.95. Dynamic loss 30 BPH. At 11,053’ 300 GPM/MPD 288 800 PSI hole unloaded Max Gas 1,477U density out 10.85. Made hook 11,012’ MD. Flow In/Out 320/318, 850 PSI. Pull speed 5 ft/min.;Dynamic losses slowing to ~15-20 BPH. At 10,867’ packed off Flow In/ Out 400/ 114 GPM slacked off, reduce flow In/ Out 350/ 341 GPM 981 PSI. Cont BROOH. Out of zone F/ 11,120’ to 10,638’ MD NB Sand Base for close approach J-25. PB1 at 11,240' MD. Lost 105 bbls for tour;PJSM BROOH F/ 10,903' to 9,376 MD Flow In/Out 500/ 427 GPM, 1,465 PSI, 100 RPM, TRQ 14.5-15.5K, ECD 10.42. P/U 150K, SLK 68K, ROT 103K. Max Gas 703U. MPD full open. Seeing dynamic loss 8-10 bph but ballooning it back at connections. Lost 20 bbls.;By 10,160' MD Staged up pump rate F/ 350 GPM to 500 GPM stage up pulling speed F/ 5 -35 ft/min. Dynamic loss ~3 BPH.;Daily fluid hauled to G&I 1,849 bbls total = 13,747 bbls Daily metal recovered 3 lbs, total = 43 lbs Daily water hauled from A Pad Lake 910 bbls total = 12,840bbls Daily fluid lost to production formation 180 Total= 934 bbls Fluid lost on surface hole = 112 bbls 7/15/2020 PJSM BROOH F/ 9270' - T/ 7658' MD. Flow In/Out 500/ 475 GPM, 1400 PSI, 100 RPM, TRQ 13.5-15.5K, ECD 10.3. P/U 144K, SLK 70K, ROT 100K. Max Gas 630u. MPD full open. Seeing dynamic loss 8-10 bph but ballooning it back at connections. Lost 25 bbls. Packing off w/ 5k tq swings @ 8870', 7721' MD.;Work up while backreaming thru notable trouble spots @ 8867' & 7721' MD. Reduced parameters and pulling speed to 1-2 fpm, stage up as hole allows.;PJSM BROOH F/ 7658' - T/ 6591' MD. Flow In/Out 500/ 468 GPM, 1050 PSI, 80-100 RPM, TRQ 13K, ECD 10.3. P/U 164K, SLK 74K, ROT 95K. Max Gas 1346u. MPD full open. Seeing dynamic loss 4-15 bph but ballooning it back at connections. 25k overpull, 5k tq inc/stall and packing off @ 6792' MD.;At 6792' to 6591' MD, Reduce pulling speed to 1-2 fpm, circulate around 51 bbl Hi vis sweep (9.2 mw, 291 vis). Circulated 2x btms up while pulling slow. ECD's dropped from 11.4 to 10.4. Sweep showed slight increase in cuttings (10%). Stage up parameters as hole allows.;PJSM BROOH F/ 6,591' to 6,190 MD Flow In/Out 450/ 449 GPM, 1,210 PSI, 90 RPM, TRQ 11-13.5K, ECD 10.28. P/U 160K, SLK 80K, ROT 95K. Max Gas 425U. MPD full open. Seeing dynamic loss 4-5 bph but ballooning it back at connections. Lost 113 bbs for tour.;Cont W/ reduced puling speed 1-2 ft/min, adjusting flow up F/ 350 GPM to 450 GPM adjusting parameters as needed for intermittent losses, packing off and TRQ spikes. Maintain <1,300 PSI for 90% returns. Out of zone faults at 6,980' to 6,221' MD in NA Clay..;PJSM BROOH F/ 6,190' to 5,749’ MD Flow In/Out 435/ 410 GPM, 998 PSI, 90 RPM, TRQ 10.5-12K, ECD 9.96. P/U 145K, SLK 87K, ROT 103K. Max Gas 255U. MPD full open. Seeing dynamic loss 4-5 bph but ballooning it back at connections. Lost 16 bbss.;At 6,060' MD decreased flow rate to 435 GPM 1,040 PSI MPD 425 and staged up to 15 ft/min with out issues. Pulled BHA through Shoe at 5,694’ to 5,685' MD W/O issue.;PJSM Rot & Rec F/ 5,685' to 5,621' MD Pump 45 bbl 295 Vis 9.2 ppg CBU 2X at Flow In/Out 450/ 431 GPM, 1,040 PSI, 40 RPM, TRQ 9K, ECD 9.78. P/U 143K, SLK 87K, ROT 105K. Max Gas 255U. MPD full open Monitor well 10 min, no flow, Shut in 3 min 18 PSI, 3 min 16 PSI;Sweep back on time no increase. Density out 9.2. Dynamic loss 4 bph.;PJSM Open Coffin on Top Drive and check for hydraulic leak. Mechanic inspecting for source of leak.;Daily fluid hauled to G&I 570 bbls total = 14,317 bbls Daily metal recovered 2 lbs, total = 45 lbs Daily water hauled from A Pad Lake 780 bbls total = 13,620 bbls Daily fluid lost to production formation 158 Total= 1,092 bbls Fluid lost on surface hole = 112 bbls 7/16/2020 PJSM Remove RCD Bearing. Align Stack and install trip nipple. Tighten grey loc clamp and air boot. L/D RCD Bearing.;PJSM POOH L/D 5" D.P. F/ 5,685' to 5,049' MD seeing slight swabbing. Correct displacement. Pump 15 bbl 10.5 ppg Dry Job. Blow down Top Drive. Install stripping rubber and air slips. Cont L/D 5" D.P. F/ 5,049' to 2,728' MD. P/U 101K SLK 82K Lost 4.9 bbls. Cull DP for CAT 5 in Pipe Shed.;PJSM Cont POOH L/D 5" D.P. F/ 2,728' to 280' MD. P/U 55K SLK 50K Lost 3.2 bbls. Pull air slips and stripping rubber. Cull DP for CAT 5 in Pipe Shed.;PJSM L/D BHA #3 as per DD & MWD. Retrieve drift at top of float, corrosion ring at NM FC. Abnormal wear on ILS . Bit Grade 3-2-CT-A-X-I-WT-TD Upload at MWD. Unable to down ADR on rig floor. Was able to down load on ground. Load 193 ea 7.5" Centralizers and stop rings. Static loss 1 bph.;PJSM P/U Weatherford 4.5" tools and Equip. R/U and function power tongs. Static loss 1 bph.;PJSM RIH 4.5" 625W 13.5# L-80 P/U M/U non ported Eccentric Shoe W/ 2 Cent on jnt Cont RIH W/ 250 RGL Screens as per tally to 5,400' MD. TRQ 9.6 W625. Install 7.5" Centralizers and Stop rings every jnt. P/U 89K SLK 69K. Calc Disp 24 bbls, actual 9.5 lost 14.5 bbls;PJSM RIH 4.5" 625W 13.5# L-80 F/ 5,400' to 8,340' MD. install 250u Screens as per tally.TRQ 9.6K W625. Install 7.5" Centralizers and Stop rings every jnt. At Shoe 5,694' MD P/U 91K SLK 68K No issues. P/U 103K SLK 60K. Tight spot at 6,920'Calc Disp 14 bbls, actual 7.1 lost 6.9 bbls.;Ran 14 ea Screens, 1 ea Water Swell Packer. Total 187 ea 7.5" Centralizers & 189 ea Stop Rings. Number of Jnts left 79 Jnts, 8 ea centralizer & 8 ea stop rings.;PJSM C/O 4.5" to 5" Handling Equip. P/U M/U 9 5/8" X 7" SLZXP Liner Packer and 2 3/8"Rupture Disc, Ball Seat & Circ. Sub 6 pin 4,800 PSI shear as per Baker Rep onsite. M/U to 4.5" Liner and RIH W/ 1 stand 5" D.P. F/ 8,340' to 8,441' MD;9 ea 7/16" set screws, 44,100 # set force. Hydraulic Setting tool 8 ea 1/2"Brass screws shear 2,648 PSI, 14 ea 1/2" Brass screws neutralize press 4,186 PSI, Get parameters: 5 RPM 5.5 K TRQ, 10 RPM 6K TRQ, 1 BPM 64 PSI, 2 BPM 86 PSI. P/U 107K SLK 64K ROT 80K.;PJSM Convey 4.5" Liner & SLZXP W/ 5" D.P. F/ Derrick F/ 8,441' to 10,096' MD. Topping off every 5 stands. P/U 126K SLK 72K. Disp 15.1 bbls, actual 10.8 bbls, lost 4.3 bbls.;PJSM Cont W/ single Jnts F/ Skate 5" HWDP F/ 10,096' to 10,438' MD. (Drift 2.75" OD) Topping off every 6 stands. P/U 135K SLK 76K Disp 3.45 bbls, actual 1 bbl, lost 2.45 bbls.;Daily fluid hauled to G&I 114 bbls total = 14,431 bbls Daily metal recovered 0 lbs, total = 45 lbs Daily water hauled from A Pad Lake 260 bbls total = 13,880 bbls Daily fluid lost to production formation 20 Total= 1,142 bbls Fluid lost on surface hole = 112 bbls 7/17/2020 Continue running 4.5" 625 Wedge, 13.5# injection liner on 5" DP / 5" HWDP F/ 10,438' - T/ 13,880' MD. Drift 2.75". Passed ST point @ 11,240' without issue. 43 bbl loss for total trip in. 1 bpm static loss rate.;Put 4.5" liner on depth. ~5513' MD TOL, 13880' MD shoe depth. 240k up, 128k dn. Establish circulation 1 bpm - 200 psi, 2 bpm - 268 psi, 3 bpm - 355 psi. Park liner in tension 225k up, TOL @ 5513' MD, Shoe @ 13,880' MD.;Drop 29/32" phenolic setting ball and pump dn @ 3 bpm, slowing to 1 bpm @ 700 stks (1010 calc). Bump @ 928 stks. Psi up 1/2 bpm to 3100 psi. Shear and set packer @ 2850 psi. Psi up and hold 3100 psi for 5 min. S/O to 75k. Linueup on test pump. Psi up and shear circ sub / burst disc @ 4500 psi;P/U with free pipe @ 203k up. Lineup and P/T annulus to 1500 psi w/ 10 min hold (chart and record same, Good Test). B/D and R/D test equipment.;POOH F/ 5513' - T/ 5465' MD. Pump dry job, B/D TDS. POOH laying down 5" HWDP and 5" DP F/ 5465' - T/ LRT. B/O and L/D same. Rupture disc sheared.;PJSM P/U M/U 3.5" Mule Shoe 3.5" Stinger 30.71', 29.57 to No/Go 8.4".;PJSM RIH W/ No/Go on 5" D.P. F/ Derrick to 5,500' MD. Wash down 2 bpm 140 PSI, tag 5K 2X TOL at 5,515' MD. P/U 130 SLK 90. Disp Calc 48 bbls, actual 42, lost 6 bbls for trip.;PJSM Rot & Rec F/ 5,496' to 5,491' MD. CBU 420 GPM, 390 PSI, 30 RPM, 8K TRQ, P/U 130K, SLK 90K ROT 108K. Max Gas 41U. Monitor well 10 min, static. Pump dry job. SPR at 5,500' ( 3,810' TVD) MW 9.2 MP #1 32-124, 48-125 MP #2 32-142, 48-144;PJSM POOH L/D 5" D.P. F/ 5,500' to 1,683' MD. P/U 71K SLK 68K Calc 33.6 bbls, actual 35.5. lost 1.9 bbls.;PJSM RIH W/ last 5" D.P. F/ Derrick F/ 1,683' to 5,117' MD. P/U 132K SLK 92K. Calc 28 bbls, actual 25.4 lost 2.6 bbls.;PJSM Cut and slip. Prep tools and Equip. Hang blocks. Last report for drilling. Change to completion AFE.;Daily fluid hauled to G&I 290 bbls total = 14,721 bbls Daily metal recovered 0 lbs, total = 45 lbs Daily water hauled from A Pad Lake 0 bbls total = 13,880 bbls Daily fluid lost to production formation 63 Total= 1,205 bbls Fluid lost on surface hole = 112 bbls Activity Date Ops Summary 7/18/2020 Continue cut and slip drilling line. Service rig. Calibrate blocks. Perform derrick inspection.,POOH F/ 5117' - T/ surface laying down remaining 5" DP along w/ 3.5" mule shoe NoGo (8.4"). 14 bbl loss for trip.,Remove wear bushing. R/U 3.5" Weatherford handling eqipment (75T YT). Double stack power tongs. Count 3.5" tubing in shed (189 jts). FOSV XO.,PJSM, M/U 7.30" OD seal assy w/ 8.26" NoGo. RIH w/ 3.5" 8rd EUE, 9.3#, L-80 upper completion F/ surface to 2,850'. 3200 ft/lbs tq. Ran 10 CC after Gauge Mandrel, every other one after.,PJSM Cont RIH 3.5" Completion Tubing F/2,850' to TAG Shoe depth 5,528.72', No/Go at 5,519.14' TOL. L/D Jnts 176, 175 & 174. Perform space out. P/U M/U 8.18', 8.12, 4.08' Pups & Jnt 174. Puts No/Go 1.65' off TOL. 7.93' swallow P/U 73K SLK 59K. Lost total 13 bbls for run. Test I Wire every 1,000'. Drift 2.867" OD. TRQ 8rd EUE 3.2K.Ttotal 84 ea. 1 ea Gauge Clamp, 174 Jnts, 3 Pups, XN Nipple, Gauge Mandrel and Seal Assy.,PJSM P/U Landing jnt and X/O to Hanger. Made up Hanger in mouse hole a couple turns. Picked up and attempted to tighten 3.5" TCII to Hanger and galled threads. Filed, chased and cleaned threads in Hanger. Was able to get the 8 turns needed. Ran Hanger and new X/O on landing joint. No spare FMC Hanger.,PJSM Centrilift Terminate I Wire. Land Hanger and NOS verified at well head. P/U 73K SLK 60K. R/U HP lines to reverse Circ. P/U 2' close annular and press up to 500 PSI for 5 min, good. Bleed down to 250 PSI and expose ports. Unable to pull through Annular due to X/O's. Space out 10' measured. Close annular. Break Circ at 2 bpm 175 PSI,PJSM Reverse Circ. 280 bbls 9.2 ppg 2% KCL/ NaCl Corrosion Inhibited Brine,130 Diesel and 12 bbls H2O to clear lines. Pump at 6 bom ICP 370 PSI, FCP 570 PSI. Lost 14 bbls.,PJSM Slack off land Hanger and RILDS. Bleed off Press.,PJSM R/U HP and jewelry to 9 5/8" X 3.5" IA. Press up to 2,500 PSI for 30 min on chart. Pumped 4.0 bbls, bled back 3.6 bbls. Witnessed waived by AOGCC Rep Brain Bixby.,PJSM R/D test lines. Back out landing Jnt F/ Hanger and L./D. Clear out stack W/ Vac Truck. Set BPV as per NOS.,Daily fluid hauled to G&I 285 bbls total = 15,006 bbls Daily metal recovered 0 lbs, total = 45 lbs Daily water hauled from A Pad Lake 0 bbls total = 13,880 bbls Daily fluid lost to production formation 38 Total= 1,243 bbls Fluid lost on surface hole = 112 bbls 7/19/2020 PJSM, Hot bolt stack, DSA, and spacer spool. Flush surface equipment. B/D TDS, MP's and all surface lines. Drain stack. De-energize koomey. R/D koomey lines. Remove riser, MPD. N/D stack and rack back same. Demob Weatherford equipment from rig floor. L/D Mousehole. Offload spent mud from pits and clean same. Inspect mud pumps. Check tire psi for move. Set herculite and mats I-38.,Prep wellhead and adapter flange. N/U tree and tq flanges. Set CTS in BPV. Test void (500/5000 psi w/ 5/15 min hold), Test good. Test tree 500/5000 (test good). Remove CTS. Final check on Tech gauge wire - PT 1645.7 psi, PA 1489.39 psi, TT 75.3°, FA 75.5°, VX 0, VZ -, Tool voltage 20.9v. Continue clean pits. N/U diverter "T" on well I-38.,R/D rig floor. PJSM, Scope down derrick. Secure well (shut all valves). Demob MPD shack. Freeze protect 3.5" tbg - Bullhead 18 bbls diesel, 2 bpm, 527 psi FCP, SITP 387 psi. Swap to Gen Power @ 17:00 hrs. SIMOPS Disconnect Interconnects. Stage Enviro Vac and Break Shack. Stage Well Head and components behind I-38.,PJSM Cont staging Equip. Peak trucks on location at 22:00. Split and stage Pipe Shed, Motor Mod, Pit Mod and Catwalk. Walk Sub of I-37 and crab over to I-38. SIMOPS Remove DS stairs F/ catwalk and 2nd story landing for clearance on I-38. Rig Released st 00:00. Final Report.,Daily fluid hauled to G&I 1,021 bbls total = 16,027 bbls Daily metal recovered 0 lbs, total = 45 lbs Daily water hauled from A Pad Lake 0 bbls total = 13,880 bbls Total lost completion: 54 bbls Total lost injection hole= 1,205 bbls Fluid lost on surface hole = 112 bbls 6/29/2020Spud Date: Well Name: Field: County/State: MPU I-37 Milne Point Hilcorp Energy Company Composite Report Alaska 50-029-23682-00-00API #: TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 1 90 19 13 13 X Yes No X Yes No 60 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 1.17 7/5/2020 25 Spud Mud Type I/II 514 2.35 Class G 400 1.15 5 1,931.37 Crossover 9 5/8 47.0 L-80 TXP x DWC 38.20 1,931.37 1,893.17 1,953.52 1,950.70 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 19.33 1,950.70 19.58 1,973.10 1,953.52 ES Cementer 10 3/4 40.0 L-80 TXP Halliburton 2.82 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 5,572.73 Casing 9 5/8 40.0 L-80 TXP Tenaris 3,599.63 5,572.73 1,973.10 5,611.93 5,574.18 Baffle Adapter 10 3/4 40.0 L-80 TXP Halliburton 1.45 5,574.18 1.38 5,613.31 5,611.93 Casing 9 5/8 40.0 L-80 TXP Tenaris 37.75 Float Collar 10 3/4 40.0 L-80 BTC Innovex (2) on shoe Joint. (1) every joint to 4692', (1) every third joint to 2211', (1) every joint to 1552' (five before, 10 after ES cementer), (1) every third joint to 238'. Casing 9 5/8 40.0 L-80 TXP Tenaris 79.09 5,692.40 5,613.31 www.wellez.net WellEz Information Management LLC ver_04818br 5208.34Water 4 Ftg. Returned 678.53 Ftg. Cut Jt.29.21 Ftg. Balance No. Jts. Delivered 159 No. Jts. Run 142 17 Length Measurements W/O Threads Ftg. Delivered 6,330.06 Ftg. Run 5,622.32 26.55 RKB to CHF Type of Shoe:Bullnose Casing Crew:Weatherford 25.52 12 215 Water #N/A Closure OK 5208.34 56 ArcticCem Type Class G 269 Tuned Spacer 553 2.94 Stage Collar @ 60 Bump press 100 224 5,694.005,704.00 CEMENTING REPORT Csg Wt. On Slips:115,000 Spud Mud 12:10 7/4/2020 1,950 1950.7 15.8 82 Bump press Returns Bump Plug? #N/A 4 9.4 3 122/123 413/398 1472 37 Rig/HESFIRST STAGE10Tuned Spacer 60 15.8 563 9.4 3 1870 10 10.7 290 5 85 675 Bump Plug? Csg Wt. On Hook:235,000 Type Float Collar:Conventional No. Hrs to Run:14 595.38 557.10 519.62 557.10 37.48 38.28Crossover 9 5/8 47.0 L-80 TXP x TCII Cut Joint 9 5/8 47.0 L-80 37.48 Tenaris 531.11 L-80 TCII VAM 1,126.49 TCII VAM 11.96 9 5/8 47.0 9 5/8 47.0 L-80 TXP 9 5/8 47.0 L-80 DWC VAM 1,164.719 5/8 47.0 L-80 DWC x TXP 38.22 BTC Innovex 1.60 5,694.00 5,692.40 1,126.49 595.38 728.46 1,893.17 1,164.71 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP I-37 Date Run 3-Jul-20 CASING RECORD County State Alaska Supv.J Lott / C. Montague 5,611.93 Floats Held 363 643 261 382 Spud Mud / Spacer Rotate Csg Recip Csg Ft. Min. PPG9.4 Shoe @ 5694 FC @ Top of Liner 5572.73 SECOND STAGERig 2:32 Returns 312.3 331.3 6 Casing Casing Casing (Or Liner) Detail Shoe Casing Crossover 10 3/4 40.0 L-80 14 July, 2020 Milne Point M Pt I Pad MPU I-37i 500292368200 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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: MPU I-37i, Slot 30 usft usft 0.00 0.00 6,009,449.41 551,569.87 31.70Wellhead Elevation:33.90 usft0.50 70° 26' 11.632 N 149° 34' 46.351 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-37i Model NameMagnetics IFR 7/10/2020 15.91 80.86 57,379.40000000 Phase:Version: Audit Notes: Design MPU I-37i 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:11,213.65 357.440.000.0026.55 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 7/14/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing72.00 820.00 MPU I-37PB1 E-Line Gyro (MPU I-37PB1 06/29/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa887.89 5,665.56 MPU I-37PB1 MWD+IFR2_MS+Sag (1) (07/01/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,742.60 11,213.65 MPU I-37PB1 MWD+IFR2+MS+Sag (2) (07/08/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa11,240.00 15,727.96 MPU I-37i MWD+IFR2+MS+Sag (3) (MP 07/13/2020 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 26.55 0.00 0.00 26.55 0.00 0.00-33.90 6,009,449.41 551,569.87 0.00 0.00 UNDEFINED 72.00 0.03 186.43 72.00 -0.01 0.0011.55 6,009,449.40 551,569.87 0.07 -0.01 3_Gyro-GC_Csg (1) 132.00 0.30 222.40 132.00 -0.14 -0.1171.55 6,009,449.27 551,569.76 0.46 -0.14 3_Gyro-GC_Csg (1) 192.00 0.19 271.31 192.00 -0.26 -0.31131.55 6,009,449.15 551,569.56 0.38 -0.24 3_Gyro-GC_Csg (1) 254.00 0.33 274.92 254.00 -0.24 -0.60193.55 6,009,449.17 551,569.28 0.23 -0.21 3_Gyro-GC_Csg (1) 316.00 0.73 318.25 316.00 0.07 -1.04255.55 6,009,449.47 551,568.83 0.87 0.12 3_Gyro-GC_Csg (1) 379.00 1.69 337.96 378.98 1.23 -1.65318.53 6,009,450.63 551,568.21 1.64 1.30 3_Gyro-GC_Csg (1) 441.00 2.54 343.79 440.94 3.40 -2.38380.49 6,009,452.79 551,567.47 1.41 3.50 3_Gyro-GC_Csg (1) 503.00 4.24 341.45 502.83 6.89 -3.49442.38 6,009,456.28 551,566.33 2.75 7.04 3_Gyro-GC_Csg (1) 566.00 6.00 329.68 565.58 11.94 -5.89505.13 6,009,461.31 551,563.89 3.24 12.19 3_Gyro-GC_Csg (1) 628.00 6.03 315.41 627.24 17.06 -9.82566.79 6,009,466.40 551,559.94 2.41 17.48 3_Gyro-GC_Csg (1) 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 691.00 5.35 306.96 689.93 21.18 -14.49629.48 6,009,470.49 551,555.24 1.71 21.81 3_Gyro-GC_Csg (1) 756.00 5.49 294.56 754.64 24.29 -19.74694.19 6,009,473.57 551,549.97 1.81 25.15 3_Gyro-GC_Csg (1) 820.00 5.16 289.87 818.36 26.55 -25.23757.91 6,009,475.78 551,544.46 0.85 27.65 3_Gyro-GC_Csg (1) 887.89 6.90 289.93 885.88 28.97 -31.93825.43 6,009,478.16 551,537.74 2.56 30.37 3_MWD+IFR2+MS+Sag (2) 951.40 8.40 294.05 948.82 32.16 -39.76888.37 6,009,481.30 551,529.90 2.51 33.91 3_MWD+IFR2+MS+Sag (2) 1,013.83 10.07 294.63 1,010.44 36.30 -48.88949.99 6,009,485.37 551,520.74 2.68 38.44 3_MWD+IFR2+MS+Sag (2) 1,078.66 11.53 294.53 1,074.12 41.35 -59.931,013.67 6,009,490.34 551,509.66 2.25 43.99 3_MWD+IFR2+MS+Sag (2) 1,142.05 12.12 296.90 1,136.16 46.99 -71.631,075.71 6,009,495.90 551,497.93 1.21 50.14 3_MWD+IFR2+MS+Sag (2) 1,205.58 12.24 287.91 1,198.27 52.08 -83.981,137.82 6,009,500.90 551,485.54 2.99 55.78 3_MWD+IFR2+MS+Sag (2) 1,269.65 13.24 277.19 1,260.77 55.09 -97.731,200.32 6,009,503.81 551,471.77 4.00 59.40 3_MWD+IFR2+MS+Sag (2) 1,332.82 13.37 271.09 1,322.25 56.13 -112.211,261.80 6,009,504.76 551,457.29 2.23 61.09 3_MWD+IFR2+MS+Sag (2) 1,396.39 13.34 270.03 1,384.10 56.28 -126.891,323.65 6,009,504.80 551,442.60 0.39 61.89 3_MWD+IFR2+MS+Sag (2) 1,459.07 15.88 272.29 1,444.75 56.62 -142.691,384.30 6,009,505.04 551,426.80 4.15 62.94 3_MWD+IFR2+MS+Sag (2) 1,522.92 18.47 274.11 1,505.74 57.70 -161.511,445.29 6,009,505.98 551,407.98 4.14 64.85 3_MWD+IFR2+MS+Sag (2) 1,587.67 20.69 273.41 1,566.75 59.11 -183.161,506.30 6,009,507.25 551,386.32 3.45 67.23 3_MWD+IFR2+MS+Sag (2) 1,651.23 22.85 272.08 1,625.77 60.23 -206.711,565.32 6,009,508.20 551,362.77 3.49 69.40 3_MWD+IFR2+MS+Sag (2) 1,714.61 25.94 271.07 1,683.48 60.93 -232.871,623.03 6,009,508.73 551,336.60 4.92 71.27 3_MWD+IFR2+MS+Sag (2) 1,778.33 28.32 270.90 1,740.19 61.43 -261.921,679.74 6,009,509.02 551,307.55 3.74 73.07 3_MWD+IFR2+MS+Sag (2) 1,842.37 30.42 271.80 1,796.00 62.18 -293.321,735.55 6,009,509.55 551,276.16 3.35 75.22 3_MWD+IFR2+MS+Sag (2) 1,905.62 33.03 270.68 1,849.79 62.89 -326.571,789.34 6,009,510.03 551,242.91 4.23 77.41 3_MWD+IFR2+MS+Sag (2) 1,969.25 36.94 269.98 1,901.91 63.09 -363.041,841.46 6,009,509.98 551,206.44 6.18 79.24 3_MWD+IFR2+MS+Sag (2) 2,033.25 40.96 269.16 1,951.68 62.77 -403.271,891.23 6,009,509.39 551,166.22 6.33 80.72 3_MWD+IFR2+MS+Sag (2) 2,096.13 43.14 269.03 1,998.37 62.11 -445.371,937.92 6,009,508.43 551,124.12 3.47 81.94 3_MWD+IFR2+MS+Sag (2) 2,159.46 46.00 267.79 2,043.48 60.86 -489.791,983.03 6,009,506.88 551,079.72 4.72 82.68 3_MWD+IFR2+MS+Sag (2) 2,223.59 44.20 267.51 2,088.74 59.00 -535.182,028.29 6,009,504.70 551,034.35 2.82 82.84 3_MWD+IFR2+MS+Sag (2) 2,287.19 46.60 269.95 2,133.40 58.02 -580.442,072.95 6,009,503.41 550,989.10 4.66 83.88 3_MWD+IFR2+MS+Sag (2) 2,349.70 48.23 271.95 2,175.70 58.79 -626.462,115.25 6,009,503.86 550,943.08 3.51 86.71 3_MWD+IFR2+MS+Sag (2) 2,413.79 48.10 272.82 2,218.45 60.78 -674.162,158.00 6,009,505.52 550,895.37 1.03 90.83 3_MWD+IFR2+MS+Sag (2) 2,477.59 49.81 272.80 2,260.34 63.13 -722.222,199.89 6,009,507.54 550,847.30 2.68 95.33 3_MWD+IFR2+MS+Sag (2) 2,540.09 50.02 273.56 2,300.59 65.79 -769.972,240.14 6,009,509.87 550,799.54 0.99 100.11 3_MWD+IFR2+MS+Sag (2) 2,604.45 49.56 273.29 2,342.14 68.72 -819.032,281.69 6,009,512.46 550,750.47 0.78 105.24 3_MWD+IFR2+MS+Sag (2) 2,668.32 49.49 274.85 2,383.60 72.17 -867.492,323.15 6,009,515.58 550,701.99 1.86 110.85 3_MWD+IFR2+MS+Sag (2) 2,731.70 50.18 274.08 2,424.48 75.94 -915.782,364.03 6,009,519.01 550,653.68 1.43 116.77 3_MWD+IFR2+MS+Sag (2) 2,794.94 48.41 274.27 2,465.72 79.43 -963.592,405.27 6,009,522.17 550,605.85 2.81 122.39 3_MWD+IFR2+MS+Sag (2) 2,859.49 47.31 274.38 2,509.03 83.04 -1,011.312,448.58 6,009,525.45 550,558.10 1.71 128.13 3_MWD+IFR2+MS+Sag (2) 2,922.34 45.99 274.31 2,552.17 86.50 -1,056.882,491.72 6,009,528.59 550,512.51 2.10 133.62 3_MWD+IFR2+MS+Sag (2) 2,986.16 47.69 275.80 2,595.82 90.61 -1,103.252,535.37 6,009,532.38 550,466.12 3.16 139.80 3_MWD+IFR2+MS+Sag (2) 3,049.75 49.73 274.89 2,637.78 95.06 -1,150.822,577.33 6,009,536.50 550,418.53 3.38 146.36 3_MWD+IFR2+MS+Sag (2) 3,113.20 48.75 275.75 2,679.21 99.51 -1,198.672,618.76 6,009,540.62 550,370.65 1.85 152.95 3_MWD+IFR2+MS+Sag (2) 3,176.71 49.81 274.72 2,720.64 103.90 -1,246.612,660.19 6,009,544.68 550,322.70 2.07 159.47 3_MWD+IFR2+MS+Sag (2) 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 3,240.44 49.98 272.91 2,761.70 107.14 -1,295.242,701.25 6,009,547.58 550,274.05 2.19 164.89 3_MWD+IFR2+MS+Sag (2) 3,304.45 49.21 275.23 2,803.19 110.59 -1,343.852,742.74 6,009,550.70 550,225.42 3.01 170.51 3_MWD+IFR2+MS+Sag (2) 3,367.43 47.59 277.87 2,845.01 115.95 -1,390.632,784.56 6,009,555.73 550,178.60 4.05 177.95 3_MWD+IFR2+MS+Sag (2) 3,430.54 47.70 281.90 2,887.54 123.96 -1,436.562,827.09 6,009,563.42 550,132.63 4.72 188.00 3_MWD+IFR2+MS+Sag (2) 3,495.08 48.33 284.28 2,930.71 134.82 -1,483.282,870.26 6,009,573.96 550,085.84 2.91 200.94 3_MWD+IFR2+MS+Sag (2) 3,558.79 49.71 286.88 2,972.50 147.75 -1,529.602,912.05 6,009,586.57 550,039.44 3.77 215.92 3_MWD+IFR2+MS+Sag (2) 3,622.14 50.59 290.04 3,013.10 163.16 -1,575.722,952.65 6,009,601.65 549,993.22 4.07 233.37 3_MWD+IFR2+MS+Sag (2) 3,686.43 50.87 293.78 3,053.80 181.72 -1,621.882,993.35 6,009,619.90 549,946.93 4.52 253.99 3_MWD+IFR2+MS+Sag (2) 3,749.94 50.27 297.76 3,094.15 203.04 -1,666.043,033.70 6,009,640.90 549,902.63 4.93 277.25 3_MWD+IFR2+MS+Sag (2) 3,813.25 51.25 301.69 3,134.20 227.35 -1,708.603,073.75 6,009,664.92 549,859.90 5.05 303.44 3_MWD+IFR2+MS+Sag (2) 3,876.08 51.84 304.32 3,173.28 254.15 -1,749.853,112.83 6,009,691.43 549,818.47 3.41 332.06 3_MWD+IFR2+MS+Sag (2) 3,940.15 53.22 307.99 3,212.26 284.15 -1,790.893,151.81 6,009,721.15 549,777.23 5.03 363.86 3_MWD+IFR2+MS+Sag (2) 4,004.05 54.39 311.15 3,250.00 317.01 -1,830.633,189.55 6,009,753.72 549,737.27 4.39 398.45 3_MWD+IFR2+MS+Sag (2) 4,067.98 55.74 313.94 3,286.62 352.44 -1,869.223,226.17 6,009,788.89 549,698.44 4.15 435.58 3_MWD+IFR2+MS+Sag (2) 4,131.31 55.99 316.65 3,322.16 389.70 -1,906.093,261.71 6,009,825.88 549,661.31 3.56 474.44 3_MWD+IFR2+MS+Sag (2) 4,195.39 56.39 319.52 3,357.82 429.31 -1,941.653,297.37 6,009,865.25 549,625.49 3.77 515.61 3_MWD+IFR2+MS+Sag (2) 4,258.78 56.05 322.32 3,393.07 470.20 -1,974.863,332.62 6,009,905.90 549,591.99 3.71 557.94 3_MWD+IFR2+MS+Sag (2) 4,322.02 56.97 324.96 3,427.97 512.67 -2,006.123,367.52 6,009,948.15 549,560.45 3.77 601.77 3_MWD+IFR2+MS+Sag (2) 4,384.83 59.01 326.95 3,461.27 556.81 -2,035.933,400.82 6,009,992.07 549,530.34 4.21 647.19 3_MWD+IFR2+MS+Sag (2) 4,449.11 61.00 329.42 3,493.40 604.11 -2,065.263,432.95 6,010,039.17 549,500.68 4.54 695.75 3_MWD+IFR2+MS+Sag (2) 4,512.42 63.13 332.12 3,523.06 652.92 -2,092.563,462.61 6,010,087.78 549,473.05 5.05 745.73 3_MWD+IFR2+MS+Sag (2) 4,576.17 64.19 334.10 3,551.35 703.87 -2,118.393,490.90 6,010,138.55 549,446.87 3.24 797.79 3_MWD+IFR2+MS+Sag (2) 4,639.48 65.27 336.48 3,578.38 755.88 -2,142.313,517.93 6,010,190.38 549,422.59 3.80 850.81 3_MWD+IFR2+MS+Sag (2) 4,702.91 64.89 339.20 3,605.11 809.14 -2,164.013,544.66 6,010,243.49 549,400.53 3.93 904.99 3_MWD+IFR2+MS+Sag (2) 4,766.23 66.23 341.02 3,631.31 863.35 -2,183.623,570.86 6,010,297.56 549,380.55 3.37 960.02 3_MWD+IFR2+MS+Sag (2) 4,829.78 68.03 343.06 3,656.01 919.05 -2,201.663,595.56 6,010,353.12 549,362.12 4.10 1,016.47 3_MWD+IFR2+MS+Sag (2) 4,893.80 69.98 344.58 3,678.95 976.44 -2,218.313,618.50 6,010,410.40 549,345.07 3.77 1,074.55 3_MWD+IFR2+MS+Sag (2) 4,957.27 71.78 346.38 3,699.74 1,034.49 -2,233.343,639.29 6,010,468.34 549,329.65 3.90 1,133.21 3_MWD+IFR2+MS+Sag (2) 5,021.33 74.19 349.35 3,718.48 1,094.37 -2,246.213,658.03 6,010,528.12 549,316.37 5.81 1,193.61 3_MWD+IFR2+MS+Sag (2) 5,084.75 74.72 353.14 3,735.49 1,154.75 -2,255.503,675.04 6,010,588.42 549,306.66 5.82 1,254.34 3_MWD+IFR2+MS+Sag (2) 5,148.77 76.02 354.04 3,751.66 1,216.30 -2,262.423,691.21 6,010,649.92 549,299.32 2.44 1,316.14 3_MWD+IFR2+MS+Sag (2) 5,211.62 78.03 356.20 3,765.77 1,277.32 -2,267.623,705.32 6,010,710.90 549,293.69 4.63 1,377.33 3_MWD+IFR2+MS+Sag (2) 5,275.06 80.90 359.03 3,777.37 1,339.62 -2,270.213,716.92 6,010,773.17 549,290.67 6.30 1,439.69 3_MWD+IFR2+MS+Sag (2) 5,338.39 80.93 359.72 3,787.37 1,402.15 -2,270.893,726.92 6,010,835.69 549,289.56 1.08 1,502.18 3_MWD+IFR2+MS+Sag (2) 5,402.69 80.59 359.74 3,797.69 1,465.62 -2,271.193,737.24 6,010,899.15 549,288.82 0.53 1,565.60 3_MWD+IFR2+MS+Sag (2) 5,466.49 83.54 359.10 3,806.50 1,528.80 -2,271.833,746.05 6,010,962.31 549,287.74 4.73 1,628.74 3_MWD+IFR2+MS+Sag (2) 5,529.81 85.21 0.72 3,812.71 1,591.81 -2,271.933,752.26 6,011,025.32 549,287.21 3.67 1,691.70 3_MWD+IFR2+MS+Sag (2) 5,592.99 87.05 0.66 3,816.97 1,654.84 -2,271.173,756.52 6,011,088.34 549,287.53 2.91 1,754.63 3_MWD+IFR2+MS+Sag (2) 5,665.56 92.49 0.57 3,817.26 1,727.37 -2,270.393,756.81 6,011,160.88 549,287.81 7.50 1,827.06 3_MWD+IFR2+MS+Sag (2) 5,742.60 91.50 0.66 3,814.58 1,804.36 -2,269.563,754.13 6,011,237.86 549,288.11 1.29 1,903.93 3_MWD+IFR2+MS+Sag (3) 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 5,806.69 89.88 1.31 3,813.81 1,868.44 -2,268.463,753.36 6,011,301.94 549,288.76 2.72 1,967.89 3_MWD+IFR2+MS+Sag (3) 5,869.24 89.51 1.21 3,814.14 1,930.97 -2,267.093,753.69 6,011,364.47 549,289.71 0.61 2,030.30 3_MWD+IFR2+MS+Sag (3) 5,932.94 90.38 0.78 3,814.20 1,994.66 -2,265.983,753.75 6,011,428.16 549,290.37 1.52 2,093.88 3_MWD+IFR2+MS+Sag (3) 5,996.55 89.94 1.10 3,814.03 2,058.26 -2,264.943,753.58 6,011,491.76 549,290.98 0.86 2,157.37 3_MWD+IFR2+MS+Sag (3) 6,060.33 90.56 0.80 3,813.75 2,122.03 -2,263.883,753.30 6,011,555.53 549,291.59 1.08 2,221.03 3_MWD+IFR2+MS+Sag (3) 6,124.03 92.05 1.65 3,812.30 2,185.70 -2,262.523,751.85 6,011,619.20 549,292.51 2.69 2,284.57 3_MWD+IFR2+MS+Sag (3) 6,187.19 92.23 0.70 3,809.94 2,248.80 -2,261.223,749.49 6,011,682.30 549,293.37 1.53 2,347.55 3_MWD+IFR2+MS+Sag (3) 6,251.23 91.92 0.98 3,807.62 2,312.79 -2,260.293,747.17 6,011,746.29 549,293.87 0.65 2,411.44 3_MWD+IFR2+MS+Sag (3) 6,315.01 93.04 359.94 3,804.86 2,376.51 -2,259.773,744.41 6,011,810.00 549,293.94 2.40 2,475.07 3_MWD+IFR2+MS+Sag (3) 6,378.34 93.16 359.00 3,801.43 2,439.74 -2,260.363,740.98 6,011,873.23 549,292.92 1.49 2,538.27 3_MWD+IFR2+MS+Sag (3) 6,442.00 93.53 359.10 3,797.72 2,503.28 -2,261.413,737.27 6,011,936.75 549,291.42 0.60 2,601.79 3_MWD+IFR2+MS+Sag (3) 6,505.89 92.91 358.07 3,794.13 2,567.05 -2,262.993,733.68 6,012,000.50 549,289.41 1.88 2,665.57 3_MWD+IFR2+MS+Sag (3) 6,569.73 90.44 357.63 3,792.26 2,630.81 -2,265.383,731.81 6,012,064.24 549,286.57 3.93 2,729.37 3_MWD+IFR2+MS+Sag (3) 6,633.23 87.53 357.99 3,793.39 2,694.25 -2,267.813,732.94 6,012,127.65 549,283.71 4.62 2,792.85 3_MWD+IFR2+MS+Sag (3) 6,696.80 85.81 358.47 3,797.08 2,757.68 -2,269.773,736.63 6,012,191.06 549,281.31 2.81 2,856.31 3_MWD+IFR2+MS+Sag (3) 6,760.40 85.31 359.10 3,802.01 2,821.07 -2,271.113,741.56 6,012,254.44 549,279.53 1.26 2,919.70 3_MWD+IFR2+MS+Sag (3) 6,824.24 86.99 1.50 3,806.29 2,884.76 -2,270.783,745.84 6,012,318.12 549,279.42 4.58 2,983.31 3_MWD+IFR2+MS+Sag (3) 6,887.36 87.79 2.13 3,809.17 2,947.78 -2,268.783,748.72 6,012,381.15 549,280.98 1.61 3,046.18 3_MWD+IFR2+MS+Sag (3) 6,951.38 87.78 1.36 3,811.64 3,011.73 -2,266.833,751.19 6,012,445.10 549,282.49 1.20 3,109.97 3_MWD+IFR2+MS+Sag (3) 7,014.33 87.29 1.91 3,814.35 3,074.59 -2,265.043,753.90 6,012,507.97 549,283.85 1.17 3,172.69 3_MWD+IFR2+MS+Sag (3) 7,077.72 87.91 2.15 3,817.00 3,137.89 -2,262.793,756.55 6,012,571.27 549,285.65 1.05 3,235.82 3_MWD+IFR2+MS+Sag (3) 7,141.38 87.04 2.21 3,819.81 3,201.44 -2,260.383,759.36 6,012,634.83 549,287.63 1.37 3,299.20 3_MWD+IFR2+MS+Sag (3) 7,204.54 85.37 1.43 3,823.99 3,264.43 -2,258.373,763.54 6,012,697.83 549,289.20 2.92 3,362.04 3_MWD+IFR2+MS+Sag (3) 7,267.87 85.68 2.73 3,828.93 3,327.52 -2,256.083,768.48 6,012,760.93 549,291.05 2.10 3,424.97 3_MWD+IFR2+MS+Sag (3) 7,331.80 87.91 5.72 3,832.50 3,391.16 -2,251.383,772.05 6,012,824.60 549,295.32 5.83 3,488.34 3_MWD+IFR2+MS+Sag (3) 7,395.84 89.39 6.64 3,834.01 3,454.81 -2,244.493,773.56 6,012,888.29 549,301.77 2.72 3,551.62 3_MWD+IFR2+MS+Sag (3) 7,459.41 90.44 6.79 3,834.11 3,517.94 -2,237.053,773.66 6,012,951.46 549,308.76 1.67 3,614.35 3_MWD+IFR2+MS+Sag (3) 7,522.11 90.75 7.28 3,833.46 3,580.17 -2,229.373,773.01 6,013,013.73 549,316.01 0.92 3,676.17 3_MWD+IFR2+MS+Sag (3) 7,586.26 90.62 6.77 3,832.69 3,643.83 -2,221.533,772.24 6,013,077.44 549,323.42 0.82 3,739.42 3_MWD+IFR2+MS+Sag (3) 7,650.07 90.75 5.81 3,831.93 3,707.25 -2,214.543,771.48 6,013,140.90 549,329.97 1.52 3,802.47 3_MWD+IFR2+MS+Sag (3) 7,714.14 90.13 4.40 3,831.43 3,771.07 -2,208.843,770.98 6,013,204.75 549,335.23 2.40 3,865.96 3_MWD+IFR2+MS+Sag (3) 7,777.54 88.77 3.75 3,832.04 3,834.30 -2,204.333,771.59 6,013,268.01 549,339.29 2.38 3,928.93 3_MWD+IFR2+MS+Sag (3) 7,841.61 88.28 4.04 3,833.69 3,898.20 -2,199.983,773.24 6,013,331.93 549,343.20 0.89 3,992.57 3_MWD+IFR2+MS+Sag (3) 7,905.18 89.27 5.17 3,835.05 3,961.55 -2,194.883,774.60 6,013,395.30 549,347.86 2.36 4,055.63 3_MWD+IFR2+MS+Sag (3) 7,968.98 90.01 5.57 3,835.45 4,025.07 -2,188.913,775.00 6,013,458.86 549,353.40 1.32 4,118.82 3_MWD+IFR2+MS+Sag (3) 8,032.45 90.13 6.58 3,835.37 4,088.18 -2,182.193,774.92 6,013,522.01 549,359.68 1.60 4,181.57 3_MWD+IFR2+MS+Sag (3) 8,096.26 90.50 7.33 3,835.02 4,151.52 -2,174.473,774.57 6,013,585.39 549,366.96 1.31 4,244.50 3_MWD+IFR2+MS+Sag (3) 8,159.96 89.33 6.96 3,835.12 4,214.72 -2,166.543,774.67 6,013,648.64 549,374.45 1.93 4,307.29 3_MWD+IFR2+MS+Sag (3) 8,223.82 89.08 6.78 3,836.00 4,278.12 -2,158.903,775.55 6,013,712.08 549,381.65 0.48 4,370.28 3_MWD+IFR2+MS+Sag (3) 8,287.03 88.71 6.97 3,837.22 4,340.86 -2,151.343,776.77 6,013,774.87 549,388.78 0.66 4,432.62 3_MWD+IFR2+MS+Sag (3) 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 8,350.70 88.40 7.67 3,838.83 4,403.99 -2,143.233,778.38 6,013,838.05 549,396.45 1.20 4,495.33 3_MWD+IFR2+MS+Sag (3) 8,414.80 88.65 9.28 3,840.48 4,467.37 -2,133.793,780.03 6,013,901.49 549,405.45 2.54 4,558.22 3_MWD+IFR2+MS+Sag (3) 8,478.49 88.89 11.06 3,841.85 4,530.04 -2,122.543,781.40 6,013,964.23 549,416.26 2.82 4,620.33 3_MWD+IFR2+MS+Sag (3) 8,541.31 88.96 11.82 3,843.02 4,591.60 -2,110.093,782.57 6,014,025.87 549,428.29 1.21 4,681.27 3_MWD+IFR2+MS+Sag (3) 8,605.25 89.33 12.05 3,843.98 4,654.15 -2,096.863,783.53 6,014,088.50 549,441.08 0.68 4,743.17 3_MWD+IFR2+MS+Sag (3) 8,669.11 88.84 12.59 3,845.00 4,716.53 -2,083.243,784.55 6,014,150.97 549,454.27 1.14 4,804.88 3_MWD+IFR2+MS+Sag (3) 8,732.77 88.40 11.72 3,846.53 4,778.75 -2,069.843,786.08 6,014,213.27 549,467.24 1.53 4,866.43 3_MWD+IFR2+MS+Sag (3) 8,793.51 86.73 10.78 3,849.11 4,838.26 -2,058.003,788.66 6,014,272.86 549,478.66 3.15 4,925.36 3_MWD+IFR2+MS+Sag (3) 8,854.55 86.42 10.06 3,852.76 4,898.19 -2,046.983,792.31 6,014,332.86 549,489.27 1.28 4,984.73 3_MWD+IFR2+MS+Sag (3) 8,922.34 86.36 9.81 3,857.03 4,964.83 -2,035.313,796.58 6,014,399.57 549,500.48 0.38 5,050.78 3_MWD+IFR2+MS+Sag (3) 8,985.85 85.93 8.72 3,861.30 5,027.37 -2,025.113,800.85 6,014,462.17 549,510.25 1.84 5,112.81 3_MWD+IFR2+MS+Sag (3) 9,050.06 86.68 9.06 3,865.44 5,090.68 -2,015.203,804.99 6,014,525.54 549,519.71 1.28 5,175.61 3_MWD+IFR2+MS+Sag (3) 9,113.67 86.67 8.94 3,869.13 5,153.40 -2,005.273,808.68 6,014,588.32 549,529.21 0.19 5,237.82 3_MWD+IFR2+MS+Sag (3) 9,177.31 86.43 8.43 3,872.95 5,216.19 -1,995.683,812.50 6,014,651.17 549,538.37 0.88 5,300.13 3_MWD+IFR2+MS+Sag (3) 9,241.28 86.24 8.25 3,877.04 5,279.36 -1,986.423,816.59 6,014,714.39 549,547.19 0.41 5,362.81 3_MWD+IFR2+MS+Sag (3) 9,304.30 86.11 8.49 3,881.25 5,341.57 -1,977.273,820.80 6,014,776.66 549,555.91 0.43 5,424.55 3_MWD+IFR2+MS+Sag (3) 9,368.79 85.99 7.98 3,885.69 5,405.24 -1,968.053,825.24 6,014,840.39 549,564.68 0.81 5,487.75 3_MWD+IFR2+MS+Sag (3) 9,432.05 86.49 10.73 3,889.84 5,467.52 -1,957.793,829.39 6,014,902.73 549,574.51 4.41 5,549.51 3_MWD+IFR2+MS+Sag (3) 9,495.92 86.80 8.80 3,893.58 5,530.35 -1,946.983,833.13 6,014,965.63 549,584.89 3.06 5,611.80 3_MWD+IFR2+MS+Sag (3) 9,559.53 86.98 8.33 3,897.03 5,593.16 -1,937.523,836.58 6,015,028.50 549,593.92 0.79 5,674.12 3_MWD+IFR2+MS+Sag (3) 9,623.42 87.78 8.73 3,899.95 5,656.28 -1,928.053,839.50 6,015,091.67 549,602.94 1.40 5,736.75 3_MWD+IFR2+MS+Sag (3) 9,687.09 88.34 8.76 3,902.10 5,719.17 -1,918.383,841.65 6,015,154.62 549,612.18 0.88 5,799.15 3_MWD+IFR2+MS+Sag (3) 9,750.68 89.02 9.45 3,903.57 5,781.94 -1,908.323,843.12 6,015,217.46 549,621.81 1.52 5,861.41 3_MWD+IFR2+MS+Sag (3) 9,814.25 90.94 11.03 3,903.59 5,844.49 -1,897.023,843.14 6,015,280.08 549,632.67 3.91 5,923.39 3_MWD+IFR2+MS+Sag (3) 9,877.44 91.18 11.09 3,902.42 5,906.50 -1,884.903,841.97 6,015,342.16 549,644.36 0.39 5,984.79 3_MWD+IFR2+MS+Sag (3) 9,940.79 91.06 10.93 3,901.18 5,968.67 -1,872.803,840.73 6,015,404.41 549,656.03 0.32 6,046.36 3_MWD+IFR2+MS+Sag (3) 10,004.12 91.18 10.44 3,899.95 6,030.89 -1,861.063,839.50 6,015,466.70 549,667.34 0.80 6,108.00 3_MWD+IFR2+MS+Sag (3) 10,068.15 91.12 10.43 3,898.66 6,093.85 -1,849.463,838.21 6,015,529.74 549,678.49 0.09 6,170.38 3_MWD+IFR2+MS+Sag (3) 10,132.07 90.07 8.88 3,898.00 6,156.86 -1,838.753,837.55 6,015,592.81 549,688.78 2.93 6,232.84 3_MWD+IFR2+MS+Sag (3) 10,195.22 88.46 7.25 3,898.81 6,219.37 -1,829.893,838.36 6,015,655.38 549,697.20 3.63 6,294.90 3_MWD+IFR2+MS+Sag (3) 10,259.18 88.59 6.74 3,900.45 6,282.84 -1,822.103,840.00 6,015,718.89 549,704.55 0.82 6,357.95 3_MWD+IFR2+MS+Sag (3) 10,322.35 88.03 6.59 3,902.32 6,345.55 -1,814.773,841.87 6,015,781.65 549,711.44 0.92 6,420.28 3_MWD+IFR2+MS+Sag (3) 10,386.06 87.60 6.84 3,904.75 6,408.78 -1,807.333,844.30 6,015,844.92 549,718.45 0.78 6,483.11 3_MWD+IFR2+MS+Sag (3) 10,449.84 88.03 7.65 3,907.18 6,472.00 -1,799.293,846.73 6,015,908.19 549,726.05 1.44 6,545.91 3_MWD+IFR2+MS+Sag (3) 10,513.23 87.72 8.72 3,909.53 6,534.70 -1,790.273,849.08 6,015,970.95 549,734.63 1.76 6,608.15 3_MWD+IFR2+MS+Sag (3) 10,576.63 87.29 9.31 3,912.29 6,597.26 -1,780.353,851.84 6,016,033.56 549,744.12 1.15 6,670.20 3_MWD+IFR2+MS+Sag (3) 10,640.76 88.40 10.39 3,914.70 6,660.40 -1,769.383,854.25 6,016,096.77 549,754.65 2.41 6,732.78 3_MWD+IFR2+MS+Sag (3) 10,703.94 89.39 10.93 3,915.92 6,722.48 -1,757.703,855.47 6,016,158.92 549,765.90 1.78 6,794.27 3_MWD+IFR2+MS+Sag (3) 10,767.94 89.39 11.30 3,916.60 6,785.27 -1,745.363,856.15 6,016,221.79 549,777.80 0.58 6,856.46 3_MWD+IFR2+MS+Sag (3) 10,831.32 88.71 11.40 3,917.65 6,847.40 -1,732.893,857.20 6,016,284.00 549,789.84 1.08 6,917.97 3_MWD+IFR2+MS+Sag (3) 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 10,894.91 88.59 11.77 3,919.15 6,909.68 -1,720.123,858.70 6,016,346.36 549,802.18 0.61 6,979.61 3_MWD+IFR2+MS+Sag (3) 10,959.03 89.58 12.53 3,920.17 6,972.35 -1,706.633,859.72 6,016,409.12 549,815.24 1.95 7,041.62 3_MWD+IFR2+MS+Sag (3) 11,022.67 90.38 13.88 3,920.19 7,034.31 -1,692.093,859.74 6,016,471.17 549,829.34 2.47 7,102.87 3_MWD+IFR2+MS+Sag (3) 11,085.64 91.06 14.97 3,919.40 7,095.29 -1,676.413,858.95 6,016,532.25 549,844.61 2.04 7,163.09 3_MWD+IFR2+MS+Sag (3) 11,149.71 91.61 15.63 3,917.91 7,157.07 -1,659.513,857.46 6,016,594.14 549,861.08 1.34 7,224.05 3_MWD+IFR2+MS+Sag (3) 11,213.65 91.55 13.99 3,916.15 7,218.86 -1,643.173,855.70 6,016,656.04 549,876.99 2.57 7,285.05 3_MWD+IFR2+MS+Sag (3) 11,240.00 91.60 13.61 3,915.42 7,244.44 -1,636.893,854.97 6,016,681.66 549,883.09 1.45 7,310.32 3_MWD+IFR2+MS+Sag (4) 11,276.78 89.51 13.00 3,915.07 7,280.23 -1,628.423,854.62 6,016,717.50 549,891.31 5.92 7,345.70 3_MWD+IFR2+MS+Sag (4) 11,340.39 88.34 11.46 3,916.26 7,342.38 -1,614.953,855.81 6,016,779.74 549,904.35 3.04 7,407.19 3_MWD+IFR2+MS+Sag (4) 11,401.83 88.34 10.03 3,918.04 7,402.72 -1,603.503,857.59 6,016,840.15 549,915.38 2.33 7,466.95 3_MWD+IFR2+MS+Sag (4) 11,467.38 87.91 9.21 3,920.19 7,467.31 -1,592.553,859.74 6,016,904.81 549,925.88 1.41 7,530.99 3_MWD+IFR2+MS+Sag (4) 11,530.65 87.29 8.43 3,922.83 7,529.78 -1,582.863,862.38 6,016,967.33 549,935.14 1.57 7,592.96 3_MWD+IFR2+MS+Sag (4) 11,594.30 87.23 8.85 3,925.88 7,592.63 -1,573.313,865.43 6,017,030.25 549,944.25 0.67 7,655.33 3_MWD+IFR2+MS+Sag (4) 11,658.59 88.41 9.16 3,928.32 7,656.08 -1,563.253,867.87 6,017,093.76 549,953.87 1.90 7,718.27 3_MWD+IFR2+MS+Sag (4) 11,721.97 89.33 10.53 3,929.57 7,718.51 -1,552.423,869.12 6,017,156.26 549,964.27 2.60 7,780.15 3_MWD+IFR2+MS+Sag (4) 11,783.07 89.45 11.32 3,930.22 7,778.50 -1,540.843,869.77 6,017,216.32 549,975.43 1.31 7,839.56 3_MWD+IFR2+MS+Sag (4) 11,846.28 89.82 12.26 3,930.63 7,840.38 -1,527.933,870.18 6,017,278.28 549,987.92 1.60 7,900.80 3_MWD+IFR2+MS+Sag (4) 11,910.47 89.76 12.30 3,930.86 7,903.10 -1,514.273,870.41 6,017,341.08 550,001.14 0.11 7,962.85 3_MWD+IFR2+MS+Sag (4) 11,976.29 89.63 11.90 3,931.21 7,967.46 -1,500.483,870.76 6,017,405.53 550,014.49 0.64 8,026.52 3_MWD+IFR2+MS+Sag (4) 12,039.44 89.95 11.80 3,931.44 8,029.26 -1,487.513,870.99 6,017,467.41 550,027.03 0.53 8,087.69 3_MWD+IFR2+MS+Sag (4) 12,103.30 88.40 12.11 3,932.36 8,091.73 -1,474.283,871.91 6,017,529.96 550,039.82 2.48 8,149.50 3_MWD+IFR2+MS+Sag (4) 12,166.44 88.28 12.51 3,934.19 8,153.39 -1,460.833,873.74 6,017,591.71 550,052.85 0.66 8,210.50 3_MWD+IFR2+MS+Sag (4) 12,229.99 88.65 12.12 3,935.89 8,215.45 -1,447.283,875.44 6,017,653.86 550,065.97 0.85 8,271.90 3_MWD+IFR2+MS+Sag (4) 12,293.88 88.28 12.03 3,937.61 8,277.91 -1,433.923,877.16 6,017,716.40 550,078.89 0.60 8,333.69 3_MWD+IFR2+MS+Sag (4) 12,357.32 88.28 11.87 3,939.51 8,339.94 -1,420.793,879.06 6,017,778.52 550,091.59 0.25 8,395.08 3_MWD+IFR2+MS+Sag (4) 12,420.72 88.40 11.15 3,941.35 8,402.04 -1,408.143,880.90 6,017,840.70 550,103.81 1.15 8,456.55 3_MWD+IFR2+MS+Sag (4) 12,484.77 88.71 11.47 3,942.96 8,464.83 -1,395.583,882.51 6,017,903.57 550,115.93 0.70 8,518.72 3_MWD+IFR2+MS+Sag (4) 12,548.11 88.03 11.43 3,944.76 8,526.88 -1,383.023,884.31 6,017,965.70 550,128.07 1.08 8,580.15 3_MWD+IFR2+MS+Sag (4) 12,612.29 88.21 11.94 3,946.87 8,589.70 -1,370.023,886.42 6,018,028.60 550,140.62 0.84 8,642.32 3_MWD+IFR2+MS+Sag (4) 12,676.66 89.02 12.40 3,948.42 8,652.60 -1,356.463,887.97 6,018,091.59 550,153.75 1.45 8,704.55 3_MWD+IFR2+MS+Sag (4) 12,740.72 88.90 12.39 3,949.59 8,715.16 -1,342.713,889.14 6,018,154.23 550,167.06 0.19 8,766.43 3_MWD+IFR2+MS+Sag (4) 12,804.48 88.34 12.17 3,951.12 8,777.44 -1,329.153,890.67 6,018,216.60 550,180.19 0.94 8,828.05 3_MWD+IFR2+MS+Sag (4) 12,867.43 88.34 11.23 3,952.95 8,839.06 -1,316.393,892.50 6,018,278.30 550,192.52 1.49 8,889.03 3_MWD+IFR2+MS+Sag (4) 12,930.97 88.65 12.18 3,954.62 8,901.25 -1,303.513,894.17 6,018,340.58 550,204.98 1.57 8,950.59 3_MWD+IFR2+MS+Sag (4) 12,994.00 87.60 13.36 3,956.68 8,962.69 -1,289.583,896.23 6,018,402.10 550,218.47 2.51 9,011.35 3_MWD+IFR2+MS+Sag (4) 13,057.23 87.23 14.31 3,959.53 9,024.02 -1,274.483,899.08 6,018,463.53 550,233.15 1.61 9,071.94 3_MWD+IFR2+MS+Sag (4) 13,120.99 88.96 16.10 3,961.65 9,085.51 -1,257.773,901.20 6,018,525.13 550,249.44 3.90 9,132.62 3_MWD+IFR2+MS+Sag (4) 13,184.93 89.70 15.80 3,962.40 9,146.99 -1,240.203,901.95 6,018,586.71 550,266.58 1.25 9,193.25 3_MWD+IFR2+MS+Sag (4) 13,248.67 90.07 15.53 3,962.52 9,208.36 -1,222.993,902.07 6,018,648.20 550,283.36 0.72 9,253.79 3_MWD+IFR2+MS+Sag (4) 13,311.61 90.25 15.29 3,962.35 9,269.03 -1,206.263,901.90 6,018,708.98 550,299.67 0.48 9,313.66 3_MWD+IFR2+MS+Sag (4) 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 13,375.30 89.95 14.03 3,962.24 9,330.65 -1,190.143,901.79 6,018,770.70 550,315.36 2.03 9,374.50 3_MWD+IFR2+MS+Sag (4) 13,439.13 89.95 11.27 3,962.29 9,392.92 -1,176.173,901.84 6,018,833.07 550,328.90 4.32 9,436.08 3_MWD+IFR2+MS+Sag (4) 13,503.17 91.06 9.38 3,961.73 9,455.92 -1,164.693,901.28 6,018,896.14 550,339.94 3.42 9,498.51 3_MWD+IFR2+MS+Sag (4) 13,566.56 89.57 9.68 3,961.38 9,518.43 -1,154.193,900.93 6,018,958.71 550,350.00 2.40 9,560.49 3_MWD+IFR2+MS+Sag (4) 13,630.18 89.64 10.50 3,961.82 9,581.07 -1,143.053,901.37 6,019,021.42 550,360.71 1.29 9,622.56 3_MWD+IFR2+MS+Sag (4) 13,694.23 89.39 11.54 3,962.36 9,643.93 -1,130.813,901.91 6,019,084.36 550,372.52 1.67 9,684.82 3_MWD+IFR2+MS+Sag (4) 13,757.87 88.71 10.44 3,963.42 9,706.40 -1,118.683,902.97 6,019,146.90 550,384.22 2.03 9,746.68 3_MWD+IFR2+MS+Sag (4) 13,820.99 89.76 9.97 3,964.26 9,768.51 -1,107.493,903.81 6,019,209.08 550,394.97 1.82 9,808.23 3_MWD+IFR2+MS+Sag (4) 13,884.42 90.38 8.87 3,964.18 9,831.08 -1,097.113,903.73 6,019,271.72 550,404.92 1.99 9,870.28 3_MWD+IFR2+MS+Sag (4) 13,947.47 89.26 9.02 3,964.38 9,893.37 -1,087.313,903.93 6,019,334.06 550,414.29 1.79 9,932.06 3_MWD+IFR2+MS+Sag (4) 14,011.37 89.08 9.90 3,965.31 9,956.39 -1,076.813,904.86 6,019,397.15 550,424.35 1.41 9,994.55 3_MWD+IFR2+MS+Sag (4) 14,074.54 88.34 11.25 3,966.73 10,018.47 -1,065.223,906.28 6,019,459.30 550,435.51 2.44 10,056.05 3_MWD+IFR2+MS+Sag (4) 14,138.55 87.04 13.16 3,969.31 10,080.98 -1,051.703,908.86 6,019,521.90 550,448.60 3.61 10,117.89 3_MWD+IFR2+MS+Sag (4) 14,202.10 87.35 15.34 3,972.42 10,142.49 -1,036.083,911.97 6,019,583.51 550,463.79 3.46 10,178.65 3_MWD+IFR2+MS+Sag (4) 14,265.72 85.68 15.26 3,976.29 10,203.74 -1,019.323,915.84 6,019,644.87 550,480.12 2.63 10,239.09 3_MWD+IFR2+MS+Sag (4) 14,329.27 86.98 16.37 3,980.35 10,264.76 -1,002.043,919.90 6,019,706.00 550,496.98 2.69 10,299.27 3_MWD+IFR2+MS+Sag (4) 14,392.90 87.97 17.35 3,983.16 10,325.60 -983.603,922.71 6,019,766.96 550,515.00 2.19 10,359.22 3_MWD+IFR2+MS+Sag (4) 14,456.35 88.09 18.28 3,985.34 10,385.97 -964.203,924.89 6,019,827.45 550,533.98 1.48 10,418.67 3_MWD+IFR2+MS+Sag (4) 14,519.49 87.23 18.21 3,987.92 10,445.88 -944.453,927.47 6,019,887.50 550,553.31 1.37 10,477.64 3_MWD+IFR2+MS+Sag (4) 14,583.36 86.17 16.45 3,991.59 10,506.75 -925.453,931.14 6,019,948.49 550,571.88 3.21 10,537.60 3_MWD+IFR2+MS+Sag (4) 14,646.98 84.44 15.95 3,996.80 10,567.63 -907.763,936.35 6,020,009.49 550,589.15 2.83 10,597.63 3_MWD+IFR2+MS+Sag (4) 14,710.29 83.45 15.82 4,003.48 10,628.19 -890.533,943.03 6,020,070.15 550,605.96 1.58 10,657.35 3_MWD+IFR2+MS+Sag (4) 14,773.61 84.57 16.01 4,010.09 10,688.74 -873.263,949.64 6,020,130.82 550,622.81 1.79 10,717.08 3_MWD+IFR2+MS+Sag (4) 14,837.62 85.93 16.38 4,015.39 10,750.00 -855.473,954.94 6,020,192.20 550,640.17 2.20 10,777.48 3_MWD+IFR2+MS+Sag (4) 14,900.91 86.98 16.23 4,019.30 10,810.63 -837.743,958.85 6,020,252.94 550,657.49 1.68 10,837.26 3_MWD+IFR2+MS+Sag (4) 14,965.26 87.97 16.40 4,022.13 10,872.33 -819.683,961.68 6,020,314.76 550,675.12 1.56 10,898.09 3_MWD+IFR2+MS+Sag (4) 15,028.42 89.64 16.93 4,023.45 10,932.82 -801.573,963.00 6,020,375.37 550,692.80 2.77 10,957.71 3_MWD+IFR2+MS+Sag (4) 15,092.26 89.14 18.40 4,024.13 10,993.64 -782.203,963.68 6,020,436.32 550,711.75 2.43 11,017.61 3_MWD+IFR2+MS+Sag (4) 15,155.67 88.83 19.29 4,025.25 11,053.64 -761.723,964.80 6,020,496.45 550,731.81 1.49 11,076.64 3_MWD+IFR2+MS+Sag (4) 15,218.95 89.82 19.61 4,026.00 11,113.31 -740.653,965.55 6,020,556.25 550,752.47 1.64 11,135.30 3_MWD+IFR2+MS+Sag (4) 15,282.47 90.50 20.68 4,025.82 11,172.94 -718.783,965.37 6,020,616.03 550,773.93 2.00 11,193.89 3_MWD+IFR2+MS+Sag (4) 15,346.15 90.07 20.60 4,025.51 11,232.53 -696.333,965.06 6,020,675.77 550,795.96 0.69 11,252.42 3_MWD+IFR2+MS+Sag (4) 15,409.68 90.81 19.38 4,025.02 11,292.23 -674.613,964.57 6,020,735.61 550,817.26 2.25 11,311.09 3_MWD+IFR2+MS+Sag (4) 15,473.38 91.86 18.04 4,023.53 11,352.55 -654.193,963.08 6,020,796.06 550,837.27 2.67 11,370.44 3_MWD+IFR2+MS+Sag (4) 15,537.30 92.73 16.33 4,020.97 11,413.56 -635.323,960.52 6,020,857.20 550,855.72 3.00 11,430.55 3_MWD+IFR2+MS+Sag (4) 15,600.94 93.71 15.38 4,017.40 11,474.68 -617.963,956.95 6,020,918.43 550,872.65 2.14 11,490.83 3_MWD+IFR2+MS+Sag (4) 15,664.73 95.08 14.20 4,012.51 11,536.17 -601.723,952.06 6,020,980.03 550,888.46 2.83 11,551.54 3_MWD+IFR2+MS+Sag (4) 15,727.96 95.70 12.62 4,006.57 11,597.41 -587.123,946.12 6,021,041.35 550,902.63 2.67 11,612.06 3_MWD+IFR2+MS+Sag (4) 15,797.00 95.70 12.62 3,999.71 11,664.45 -572.113,939.26 6,021,108.49 550,917.18 0.00 11,678.36 PROJECTED to TD 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37i Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i True Approved By:Checked By:Date: 7/14/2020 6:50:25PM COMPASS 5000.15 Build 91E Page 9 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.07.14 15:52:09 -08'00' Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.07.15 12:06:44 -08'00' 15 July, 2020 Milne Point M Pt I Pad MPU I-37PB1 Richmond 500292368270 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37PB1 Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37PB1 Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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: MPU I-37i, Slot 30 usft usft 0.00 0.00 6,009,449.41 551,569.87 31.70Wellhead Elevation:33.90 usft0.50 70° 26' 11.632 N 149° 34' 46.351 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-37PB1 Model NameMagnetics IFR 7/10/2020 15.91 80.86 57,379.40000000 Phase:Version: Audit Notes: Design MPU I-37PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.55 357.440.000.0026.55 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 7/15/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing72.00 820.00 MPU I-37PB1 E-Line Gyro (MPU I-37PB1 06/29/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa887.89 5,665.56 MPU I-37PB1 MWD+IFR2_MS+Sag (1) (07/01/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,742.60 12,738.99 MPU I-37PB1 MWD+IFR2+MS+Sag (2) (07/08/2020 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 26.55 0.00 0.00 26.55 0.00 0.00-33.90 6,009,449.41 551,569.87 0.00 0.00 UNDEFINED 72.00 0.03 186.43 72.00 -0.01 0.0011.55 6,009,449.40 551,569.87 0.07 -0.01 3_Gyro-GC_Csg (1) 132.00 0.30 222.40 132.00 -0.14 -0.1171.55 6,009,449.27 551,569.76 0.46 -0.14 3_Gyro-GC_Csg (1) 192.00 0.19 271.31 192.00 -0.26 -0.31131.55 6,009,449.15 551,569.56 0.38 -0.24 3_Gyro-GC_Csg (1) 254.00 0.33 274.92 254.00 -0.24 -0.60193.55 6,009,449.17 551,569.28 0.23 -0.21 3_Gyro-GC_Csg (1) 316.00 0.73 318.25 316.00 0.07 -1.04255.55 6,009,449.47 551,568.83 0.87 0.12 3_Gyro-GC_Csg (1) 379.00 1.69 337.96 378.98 1.23 -1.65318.53 6,009,450.63 551,568.21 1.64 1.30 3_Gyro-GC_Csg (1) 441.00 2.54 343.79 440.94 3.40 -2.38380.49 6,009,452.79 551,567.47 1.41 3.50 3_Gyro-GC_Csg (1) 503.00 4.24 341.45 502.83 6.89 -3.49442.38 6,009,456.28 551,566.33 2.75 7.04 3_Gyro-GC_Csg (1) 566.00 6.00 329.68 565.58 11.94 -5.89505.13 6,009,461.31 551,563.89 3.24 12.19 3_Gyro-GC_Csg (1) 628.00 6.03 315.41 627.24 17.06 -9.82566.79 6,009,466.40 551,559.94 2.41 17.48 3_Gyro-GC_Csg (1) 691.00 5.35 306.96 689.93 21.18 -14.49629.48 6,009,470.49 551,555.24 1.71 21.81 3_Gyro-GC_Csg (1) 7/15/2020 4:40:39PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37PB1 Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37PB1 Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 756.00 5.49 294.56 754.64 24.29 -19.74694.19 6,009,473.57 551,549.97 1.81 25.15 3_Gyro-GC_Csg (1) 820.00 5.16 289.87 818.36 26.55 -25.23757.91 6,009,475.78 551,544.46 0.85 27.65 3_Gyro-GC_Csg (1) 887.89 6.90 289.93 885.88 28.97 -31.93825.43 6,009,478.16 551,537.74 2.56 30.37 3_MWD+IFR2+MS+Sag (2) 951.40 8.40 294.05 948.82 32.16 -39.76888.37 6,009,481.30 551,529.90 2.51 33.91 3_MWD+IFR2+MS+Sag (2) 1,013.83 10.07 294.63 1,010.44 36.30 -48.88949.99 6,009,485.37 551,520.74 2.68 38.44 3_MWD+IFR2+MS+Sag (2) 1,078.66 11.53 294.53 1,074.12 41.35 -59.931,013.67 6,009,490.34 551,509.66 2.25 43.99 3_MWD+IFR2+MS+Sag (2) 1,142.05 12.12 296.90 1,136.16 46.99 -71.631,075.71 6,009,495.90 551,497.93 1.21 50.14 3_MWD+IFR2+MS+Sag (2) 1,205.58 12.24 287.91 1,198.27 52.08 -83.981,137.82 6,009,500.90 551,485.54 2.99 55.78 3_MWD+IFR2+MS+Sag (2) 1,269.65 13.24 277.19 1,260.77 55.09 -97.731,200.32 6,009,503.81 551,471.77 4.00 59.40 3_MWD+IFR2+MS+Sag (2) 1,332.82 13.37 271.09 1,322.25 56.13 -112.211,261.80 6,009,504.76 551,457.29 2.23 61.09 3_MWD+IFR2+MS+Sag (2) 1,396.39 13.34 270.03 1,384.10 56.28 -126.891,323.65 6,009,504.80 551,442.60 0.39 61.89 3_MWD+IFR2+MS+Sag (2) 1,459.07 15.88 272.29 1,444.75 56.62 -142.691,384.30 6,009,505.04 551,426.80 4.15 62.94 3_MWD+IFR2+MS+Sag (2) 1,522.92 18.47 274.11 1,505.74 57.70 -161.511,445.29 6,009,505.98 551,407.98 4.14 64.85 3_MWD+IFR2+MS+Sag (2) 1,587.67 20.69 273.41 1,566.75 59.11 -183.161,506.30 6,009,507.25 551,386.32 3.45 67.23 3_MWD+IFR2+MS+Sag (2) 1,651.23 22.85 272.08 1,625.77 60.23 -206.711,565.32 6,009,508.20 551,362.77 3.49 69.40 3_MWD+IFR2+MS+Sag (2) 1,714.61 25.94 271.07 1,683.48 60.93 -232.871,623.03 6,009,508.73 551,336.60 4.92 71.27 3_MWD+IFR2+MS+Sag (2) 1,778.33 28.32 270.90 1,740.19 61.43 -261.921,679.74 6,009,509.02 551,307.55 3.74 73.07 3_MWD+IFR2+MS+Sag (2) 1,842.37 30.42 271.80 1,796.00 62.18 -293.321,735.55 6,009,509.55 551,276.16 3.35 75.22 3_MWD+IFR2+MS+Sag (2) 1,905.62 33.03 270.68 1,849.79 62.89 -326.571,789.34 6,009,510.03 551,242.91 4.23 77.41 3_MWD+IFR2+MS+Sag (2) 1,969.25 36.94 269.98 1,901.91 63.09 -363.041,841.46 6,009,509.98 551,206.44 6.18 79.24 3_MWD+IFR2+MS+Sag (2) 2,033.25 40.96 269.16 1,951.68 62.77 -403.271,891.23 6,009,509.39 551,166.22 6.33 80.72 3_MWD+IFR2+MS+Sag (2) 2,096.13 43.14 269.03 1,998.37 62.11 -445.371,937.92 6,009,508.43 551,124.12 3.47 81.94 3_MWD+IFR2+MS+Sag (2) 2,159.46 46.00 267.79 2,043.48 60.86 -489.791,983.03 6,009,506.88 551,079.72 4.72 82.68 3_MWD+IFR2+MS+Sag (2) 2,223.59 44.20 267.51 2,088.74 59.00 -535.182,028.29 6,009,504.70 551,034.35 2.82 82.84 3_MWD+IFR2+MS+Sag (2) 2,287.19 46.60 269.95 2,133.40 58.02 -580.442,072.95 6,009,503.41 550,989.10 4.66 83.88 3_MWD+IFR2+MS+Sag (2) 2,349.70 48.23 271.95 2,175.70 58.79 -626.462,115.25 6,009,503.86 550,943.08 3.51 86.71 3_MWD+IFR2+MS+Sag (2) 2,413.79 48.10 272.82 2,218.45 60.78 -674.162,158.00 6,009,505.52 550,895.37 1.03 90.83 3_MWD+IFR2+MS+Sag (2) 2,477.59 49.81 272.80 2,260.34 63.13 -722.222,199.89 6,009,507.54 550,847.30 2.68 95.33 3_MWD+IFR2+MS+Sag (2) 2,540.09 50.02 273.56 2,300.59 65.79 -769.972,240.14 6,009,509.87 550,799.54 0.99 100.11 3_MWD+IFR2+MS+Sag (2) 2,604.45 49.56 273.29 2,342.14 68.72 -819.032,281.69 6,009,512.46 550,750.47 0.78 105.24 3_MWD+IFR2+MS+Sag (2) 2,668.32 49.49 274.85 2,383.60 72.17 -867.492,323.15 6,009,515.58 550,701.99 1.86 110.85 3_MWD+IFR2+MS+Sag (2) 2,731.70 50.18 274.08 2,424.48 75.94 -915.782,364.03 6,009,519.01 550,653.68 1.43 116.77 3_MWD+IFR2+MS+Sag (2) 2,794.94 48.41 274.27 2,465.72 79.43 -963.592,405.27 6,009,522.17 550,605.85 2.81 122.39 3_MWD+IFR2+MS+Sag (2) 2,859.49 47.31 274.38 2,509.03 83.04 -1,011.312,448.58 6,009,525.45 550,558.10 1.71 128.13 3_MWD+IFR2+MS+Sag (2) 2,922.34 45.99 274.31 2,552.17 86.50 -1,056.882,491.72 6,009,528.59 550,512.51 2.10 133.62 3_MWD+IFR2+MS+Sag (2) 2,986.16 47.69 275.80 2,595.82 90.61 -1,103.252,535.37 6,009,532.38 550,466.12 3.16 139.80 3_MWD+IFR2+MS+Sag (2) 3,049.75 49.73 274.89 2,637.78 95.06 -1,150.822,577.33 6,009,536.50 550,418.53 3.38 146.36 3_MWD+IFR2+MS+Sag (2) 3,113.20 48.75 275.75 2,679.21 99.51 -1,198.672,618.76 6,009,540.62 550,370.65 1.85 152.95 3_MWD+IFR2+MS+Sag (2) 3,176.71 49.81 274.72 2,720.64 103.90 -1,246.612,660.19 6,009,544.68 550,322.70 2.07 159.47 3_MWD+IFR2+MS+Sag (2) 3,240.44 49.98 272.91 2,761.70 107.14 -1,295.242,701.25 6,009,547.58 550,274.05 2.19 164.89 3_MWD+IFR2+MS+Sag (2) 7/15/2020 4:40:39PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37PB1 Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37PB1 Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 3,304.45 49.21 275.23 2,803.19 110.59 -1,343.852,742.74 6,009,550.70 550,225.42 3.01 170.51 3_MWD+IFR2+MS+Sag (2) 3,367.43 47.59 277.87 2,845.01 115.95 -1,390.632,784.56 6,009,555.73 550,178.60 4.05 177.95 3_MWD+IFR2+MS+Sag (2) 3,430.54 47.70 281.90 2,887.54 123.96 -1,436.562,827.09 6,009,563.42 550,132.63 4.72 188.00 3_MWD+IFR2+MS+Sag (2) 3,495.08 48.33 284.28 2,930.71 134.82 -1,483.282,870.26 6,009,573.96 550,085.84 2.91 200.94 3_MWD+IFR2+MS+Sag (2) 3,558.79 49.71 286.88 2,972.50 147.75 -1,529.602,912.05 6,009,586.57 550,039.44 3.77 215.92 3_MWD+IFR2+MS+Sag (2) 3,622.14 50.59 290.04 3,013.10 163.16 -1,575.722,952.65 6,009,601.65 549,993.22 4.07 233.37 3_MWD+IFR2+MS+Sag (2) 3,686.43 50.87 293.78 3,053.80 181.72 -1,621.882,993.35 6,009,619.90 549,946.93 4.52 253.99 3_MWD+IFR2+MS+Sag (2) 3,749.94 50.27 297.76 3,094.15 203.04 -1,666.043,033.70 6,009,640.90 549,902.63 4.93 277.25 3_MWD+IFR2+MS+Sag (2) 3,813.25 51.25 301.69 3,134.20 227.35 -1,708.603,073.75 6,009,664.92 549,859.90 5.05 303.44 3_MWD+IFR2+MS+Sag (2) 3,876.08 51.84 304.32 3,173.28 254.15 -1,749.853,112.83 6,009,691.43 549,818.47 3.41 332.06 3_MWD+IFR2+MS+Sag (2) 3,940.15 53.22 307.99 3,212.26 284.15 -1,790.893,151.81 6,009,721.15 549,777.23 5.03 363.86 3_MWD+IFR2+MS+Sag (2) 4,004.05 54.39 311.15 3,250.00 317.01 -1,830.633,189.55 6,009,753.72 549,737.27 4.39 398.45 3_MWD+IFR2+MS+Sag (2) 4,067.98 55.74 313.94 3,286.62 352.44 -1,869.223,226.17 6,009,788.89 549,698.44 4.15 435.58 3_MWD+IFR2+MS+Sag (2) 4,131.31 55.99 316.65 3,322.16 389.70 -1,906.093,261.71 6,009,825.88 549,661.31 3.56 474.44 3_MWD+IFR2+MS+Sag (2) 4,195.39 56.39 319.52 3,357.82 429.31 -1,941.653,297.37 6,009,865.25 549,625.49 3.77 515.61 3_MWD+IFR2+MS+Sag (2) 4,258.78 56.05 322.32 3,393.07 470.20 -1,974.863,332.62 6,009,905.90 549,591.99 3.71 557.94 3_MWD+IFR2+MS+Sag (2) 4,322.02 56.97 324.96 3,427.97 512.67 -2,006.123,367.52 6,009,948.15 549,560.45 3.77 601.77 3_MWD+IFR2+MS+Sag (2) 4,384.83 59.01 326.95 3,461.27 556.81 -2,035.933,400.82 6,009,992.07 549,530.34 4.21 647.19 3_MWD+IFR2+MS+Sag (2) 4,449.11 61.00 329.42 3,493.40 604.11 -2,065.263,432.95 6,010,039.17 549,500.68 4.54 695.75 3_MWD+IFR2+MS+Sag (2) 4,512.42 63.13 332.12 3,523.06 652.92 -2,092.563,462.61 6,010,087.78 549,473.05 5.05 745.73 3_MWD+IFR2+MS+Sag (2) 4,576.17 64.19 334.10 3,551.35 703.87 -2,118.393,490.90 6,010,138.55 549,446.87 3.24 797.79 3_MWD+IFR2+MS+Sag (2) 4,639.48 65.27 336.48 3,578.38 755.88 -2,142.313,517.93 6,010,190.38 549,422.59 3.80 850.81 3_MWD+IFR2+MS+Sag (2) 4,702.91 64.89 339.20 3,605.11 809.14 -2,164.013,544.66 6,010,243.49 549,400.53 3.93 904.99 3_MWD+IFR2+MS+Sag (2) 4,766.23 66.23 341.02 3,631.31 863.35 -2,183.623,570.86 6,010,297.56 549,380.55 3.37 960.02 3_MWD+IFR2+MS+Sag (2) 4,829.78 68.03 343.06 3,656.01 919.05 -2,201.663,595.56 6,010,353.12 549,362.12 4.10 1,016.47 3_MWD+IFR2+MS+Sag (2) 4,893.80 69.98 344.58 3,678.95 976.44 -2,218.313,618.50 6,010,410.40 549,345.07 3.77 1,074.55 3_MWD+IFR2+MS+Sag (2) 4,957.27 71.78 346.38 3,699.74 1,034.49 -2,233.343,639.29 6,010,468.34 549,329.65 3.90 1,133.21 3_MWD+IFR2+MS+Sag (2) 5,021.33 74.19 349.35 3,718.48 1,094.37 -2,246.213,658.03 6,010,528.12 549,316.37 5.81 1,193.61 3_MWD+IFR2+MS+Sag (2) 5,084.75 74.72 353.14 3,735.49 1,154.75 -2,255.503,675.04 6,010,588.42 549,306.66 5.82 1,254.34 3_MWD+IFR2+MS+Sag (2) 5,148.77 76.02 354.04 3,751.66 1,216.30 -2,262.423,691.21 6,010,649.92 549,299.32 2.44 1,316.14 3_MWD+IFR2+MS+Sag (2) 5,211.62 78.03 356.20 3,765.77 1,277.32 -2,267.623,705.32 6,010,710.90 549,293.69 4.63 1,377.33 3_MWD+IFR2+MS+Sag (2) 5,275.06 80.90 359.03 3,777.37 1,339.62 -2,270.213,716.92 6,010,773.17 549,290.67 6.30 1,439.69 3_MWD+IFR2+MS+Sag (2) 5,338.39 80.93 359.72 3,787.37 1,402.15 -2,270.893,726.92 6,010,835.69 549,289.56 1.08 1,502.18 3_MWD+IFR2+MS+Sag (2) 5,402.69 80.59 359.74 3,797.69 1,465.62 -2,271.193,737.24 6,010,899.15 549,288.82 0.53 1,565.60 3_MWD+IFR2+MS+Sag (2) 5,466.49 83.54 359.10 3,806.50 1,528.80 -2,271.833,746.05 6,010,962.31 549,287.74 4.73 1,628.74 3_MWD+IFR2+MS+Sag (2) 5,529.81 85.21 0.72 3,812.71 1,591.81 -2,271.933,752.26 6,011,025.32 549,287.21 3.67 1,691.70 3_MWD+IFR2+MS+Sag (2) 5,592.99 87.05 0.66 3,816.97 1,654.84 -2,271.173,756.52 6,011,088.34 549,287.53 2.91 1,754.63 3_MWD+IFR2+MS+Sag (2) 5,665.56 92.49 0.57 3,817.26 1,727.37 -2,270.393,756.81 6,011,160.88 549,287.81 7.50 1,827.06 3_MWD+IFR2+MS+Sag (2) 5,742.60 91.50 0.66 3,814.58 1,804.36 -2,269.563,754.13 6,011,237.86 549,288.11 1.29 1,903.93 3_MWD+IFR2+MS+Sag (3) 5,806.69 89.88 1.31 3,813.81 1,868.44 -2,268.463,753.36 6,011,301.94 549,288.76 2.72 1,967.89 3_MWD+IFR2+MS+Sag (3) 7/15/2020 4:40:39PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37PB1 Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37PB1 Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 5,869.24 89.51 1.21 3,814.14 1,930.97 -2,267.093,753.69 6,011,364.47 549,289.71 0.61 2,030.30 3_MWD+IFR2+MS+Sag (3) 5,932.94 90.38 0.78 3,814.20 1,994.66 -2,265.983,753.75 6,011,428.16 549,290.37 1.52 2,093.88 3_MWD+IFR2+MS+Sag (3) 5,996.55 89.94 1.10 3,814.03 2,058.26 -2,264.943,753.58 6,011,491.76 549,290.98 0.86 2,157.37 3_MWD+IFR2+MS+Sag (3) 6,060.33 90.56 0.80 3,813.75 2,122.03 -2,263.883,753.30 6,011,555.53 549,291.59 1.08 2,221.03 3_MWD+IFR2+MS+Sag (3) 6,124.03 92.05 1.65 3,812.30 2,185.70 -2,262.523,751.85 6,011,619.20 549,292.51 2.69 2,284.57 3_MWD+IFR2+MS+Sag (3) 6,187.19 92.23 0.70 3,809.94 2,248.80 -2,261.223,749.49 6,011,682.30 549,293.37 1.53 2,347.55 3_MWD+IFR2+MS+Sag (3) 6,251.23 91.92 0.98 3,807.62 2,312.79 -2,260.293,747.17 6,011,746.29 549,293.87 0.65 2,411.44 3_MWD+IFR2+MS+Sag (3) 6,315.01 93.04 359.94 3,804.86 2,376.51 -2,259.773,744.41 6,011,810.00 549,293.94 2.40 2,475.07 3_MWD+IFR2+MS+Sag (3) 6,378.34 93.16 359.00 3,801.43 2,439.74 -2,260.363,740.98 6,011,873.23 549,292.92 1.49 2,538.27 3_MWD+IFR2+MS+Sag (3) 6,442.00 93.53 359.10 3,797.72 2,503.28 -2,261.413,737.27 6,011,936.75 549,291.42 0.60 2,601.79 3_MWD+IFR2+MS+Sag (3) 6,505.89 92.91 358.07 3,794.13 2,567.05 -2,262.993,733.68 6,012,000.50 549,289.41 1.88 2,665.57 3_MWD+IFR2+MS+Sag (3) 6,569.73 90.44 357.63 3,792.26 2,630.81 -2,265.383,731.81 6,012,064.24 549,286.57 3.93 2,729.37 3_MWD+IFR2+MS+Sag (3) 6,633.23 87.53 357.99 3,793.39 2,694.25 -2,267.813,732.94 6,012,127.65 549,283.71 4.62 2,792.85 3_MWD+IFR2+MS+Sag (3) 6,696.80 85.81 358.47 3,797.08 2,757.68 -2,269.773,736.63 6,012,191.06 549,281.31 2.81 2,856.31 3_MWD+IFR2+MS+Sag (3) 6,760.40 85.31 359.10 3,802.01 2,821.07 -2,271.113,741.56 6,012,254.44 549,279.53 1.26 2,919.70 3_MWD+IFR2+MS+Sag (3) 6,824.24 86.99 1.50 3,806.29 2,884.76 -2,270.783,745.84 6,012,318.12 549,279.42 4.58 2,983.31 3_MWD+IFR2+MS+Sag (3) 6,887.36 87.79 2.13 3,809.17 2,947.78 -2,268.783,748.72 6,012,381.15 549,280.98 1.61 3,046.18 3_MWD+IFR2+MS+Sag (3) 6,951.38 87.78 1.36 3,811.64 3,011.73 -2,266.833,751.19 6,012,445.10 549,282.49 1.20 3,109.97 3_MWD+IFR2+MS+Sag (3) 7,014.33 87.29 1.91 3,814.35 3,074.59 -2,265.043,753.90 6,012,507.97 549,283.85 1.17 3,172.69 3_MWD+IFR2+MS+Sag (3) 7,077.72 87.91 2.15 3,817.00 3,137.89 -2,262.793,756.55 6,012,571.27 549,285.65 1.05 3,235.82 3_MWD+IFR2+MS+Sag (3) 7,141.38 87.04 2.21 3,819.81 3,201.44 -2,260.383,759.36 6,012,634.83 549,287.63 1.37 3,299.20 3_MWD+IFR2+MS+Sag (3) 7,204.54 85.37 1.43 3,823.99 3,264.43 -2,258.373,763.54 6,012,697.83 549,289.20 2.92 3,362.04 3_MWD+IFR2+MS+Sag (3) 7,267.87 85.68 2.73 3,828.93 3,327.52 -2,256.083,768.48 6,012,760.93 549,291.05 2.10 3,424.97 3_MWD+IFR2+MS+Sag (3) 7,331.80 87.91 5.72 3,832.50 3,391.16 -2,251.383,772.05 6,012,824.60 549,295.32 5.83 3,488.34 3_MWD+IFR2+MS+Sag (3) 7,395.84 89.39 6.64 3,834.01 3,454.81 -2,244.493,773.56 6,012,888.29 549,301.77 2.72 3,551.62 3_MWD+IFR2+MS+Sag (3) 7,459.41 90.44 6.79 3,834.11 3,517.94 -2,237.053,773.66 6,012,951.46 549,308.76 1.67 3,614.35 3_MWD+IFR2+MS+Sag (3) 7,522.11 90.75 7.28 3,833.46 3,580.17 -2,229.373,773.01 6,013,013.73 549,316.01 0.92 3,676.17 3_MWD+IFR2+MS+Sag (3) 7,586.26 90.62 6.77 3,832.69 3,643.83 -2,221.533,772.24 6,013,077.44 549,323.42 0.82 3,739.42 3_MWD+IFR2+MS+Sag (3) 7,650.07 90.75 5.81 3,831.93 3,707.25 -2,214.543,771.48 6,013,140.90 549,329.97 1.52 3,802.47 3_MWD+IFR2+MS+Sag (3) 7,714.14 90.13 4.40 3,831.43 3,771.07 -2,208.843,770.98 6,013,204.75 549,335.23 2.40 3,865.96 3_MWD+IFR2+MS+Sag (3) 7,777.54 88.77 3.75 3,832.04 3,834.30 -2,204.333,771.59 6,013,268.01 549,339.29 2.38 3,928.93 3_MWD+IFR2+MS+Sag (3) 7,841.61 88.28 4.04 3,833.69 3,898.20 -2,199.983,773.24 6,013,331.93 549,343.20 0.89 3,992.57 3_MWD+IFR2+MS+Sag (3) 7,905.18 89.27 5.17 3,835.05 3,961.55 -2,194.883,774.60 6,013,395.30 549,347.86 2.36 4,055.63 3_MWD+IFR2+MS+Sag (3) 7,968.98 90.01 5.57 3,835.45 4,025.07 -2,188.913,775.00 6,013,458.86 549,353.40 1.32 4,118.82 3_MWD+IFR2+MS+Sag (3) 8,032.45 90.13 6.58 3,835.37 4,088.18 -2,182.193,774.92 6,013,522.01 549,359.68 1.60 4,181.57 3_MWD+IFR2+MS+Sag (3) 8,096.26 90.50 7.33 3,835.02 4,151.52 -2,174.473,774.57 6,013,585.39 549,366.96 1.31 4,244.50 3_MWD+IFR2+MS+Sag (3) 8,159.96 89.33 6.96 3,835.12 4,214.72 -2,166.543,774.67 6,013,648.64 549,374.45 1.93 4,307.29 3_MWD+IFR2+MS+Sag (3) 8,223.82 89.08 6.78 3,836.00 4,278.12 -2,158.903,775.55 6,013,712.08 549,381.65 0.48 4,370.28 3_MWD+IFR2+MS+Sag (3) 8,287.03 88.71 6.97 3,837.22 4,340.86 -2,151.343,776.77 6,013,774.87 549,388.78 0.66 4,432.62 3_MWD+IFR2+MS+Sag (3) 8,350.70 88.40 7.67 3,838.83 4,403.99 -2,143.233,778.38 6,013,838.05 549,396.45 1.20 4,495.33 3_MWD+IFR2+MS+Sag (3) 7/15/2020 4:40:39PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37PB1 Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37PB1 Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 8,414.80 88.65 9.28 3,840.48 4,467.37 -2,133.793,780.03 6,013,901.49 549,405.45 2.54 4,558.22 3_MWD+IFR2+MS+Sag (3) 8,478.49 88.89 11.06 3,841.85 4,530.04 -2,122.543,781.40 6,013,964.23 549,416.26 2.82 4,620.33 3_MWD+IFR2+MS+Sag (3) 8,541.31 88.96 11.82 3,843.02 4,591.60 -2,110.093,782.57 6,014,025.87 549,428.29 1.21 4,681.27 3_MWD+IFR2+MS+Sag (3) 8,605.25 89.33 12.05 3,843.98 4,654.15 -2,096.863,783.53 6,014,088.50 549,441.08 0.68 4,743.17 3_MWD+IFR2+MS+Sag (3) 8,669.11 88.84 12.59 3,845.00 4,716.53 -2,083.243,784.55 6,014,150.97 549,454.27 1.14 4,804.88 3_MWD+IFR2+MS+Sag (3) 8,732.77 88.40 11.72 3,846.53 4,778.75 -2,069.843,786.08 6,014,213.27 549,467.24 1.53 4,866.43 3_MWD+IFR2+MS+Sag (3) 8,793.51 86.73 10.78 3,849.11 4,838.26 -2,058.003,788.66 6,014,272.86 549,478.66 3.15 4,925.36 3_MWD+IFR2+MS+Sag (3) 8,854.55 86.42 10.06 3,852.76 4,898.19 -2,046.983,792.31 6,014,332.86 549,489.27 1.28 4,984.73 3_MWD+IFR2+MS+Sag (3) 8,922.34 86.36 9.81 3,857.03 4,964.83 -2,035.313,796.58 6,014,399.57 549,500.48 0.38 5,050.78 3_MWD+IFR2+MS+Sag (3) 8,985.85 85.93 8.72 3,861.30 5,027.37 -2,025.113,800.85 6,014,462.17 549,510.25 1.84 5,112.81 3_MWD+IFR2+MS+Sag (3) 9,050.06 86.68 9.06 3,865.44 5,090.68 -2,015.203,804.99 6,014,525.54 549,519.71 1.28 5,175.61 3_MWD+IFR2+MS+Sag (3) 9,113.67 86.67 8.94 3,869.13 5,153.40 -2,005.273,808.68 6,014,588.32 549,529.21 0.19 5,237.82 3_MWD+IFR2+MS+Sag (3) 9,177.31 86.43 8.43 3,872.95 5,216.19 -1,995.683,812.50 6,014,651.17 549,538.37 0.88 5,300.13 3_MWD+IFR2+MS+Sag (3) 9,241.28 86.24 8.25 3,877.04 5,279.36 -1,986.423,816.59 6,014,714.39 549,547.19 0.41 5,362.81 3_MWD+IFR2+MS+Sag (3) 9,304.30 86.11 8.49 3,881.25 5,341.57 -1,977.273,820.80 6,014,776.66 549,555.91 0.43 5,424.55 3_MWD+IFR2+MS+Sag (3) 9,368.79 85.99 7.98 3,885.69 5,405.24 -1,968.053,825.24 6,014,840.39 549,564.68 0.81 5,487.75 3_MWD+IFR2+MS+Sag (3) 9,432.05 86.49 10.73 3,889.84 5,467.52 -1,957.793,829.39 6,014,902.73 549,574.51 4.41 5,549.51 3_MWD+IFR2+MS+Sag (3) 9,495.92 86.80 8.80 3,893.58 5,530.35 -1,946.983,833.13 6,014,965.63 549,584.89 3.06 5,611.80 3_MWD+IFR2+MS+Sag (3) 9,559.53 86.98 8.33 3,897.03 5,593.16 -1,937.523,836.58 6,015,028.50 549,593.92 0.79 5,674.12 3_MWD+IFR2+MS+Sag (3) 9,623.42 87.78 8.73 3,899.95 5,656.28 -1,928.053,839.50 6,015,091.67 549,602.94 1.40 5,736.75 3_MWD+IFR2+MS+Sag (3) 9,687.09 88.34 8.76 3,902.10 5,719.17 -1,918.383,841.65 6,015,154.62 549,612.18 0.88 5,799.15 3_MWD+IFR2+MS+Sag (3) 9,750.68 89.02 9.45 3,903.57 5,781.94 -1,908.323,843.12 6,015,217.46 549,621.81 1.52 5,861.41 3_MWD+IFR2+MS+Sag (3) 9,814.25 90.94 11.03 3,903.59 5,844.49 -1,897.023,843.14 6,015,280.08 549,632.67 3.91 5,923.39 3_MWD+IFR2+MS+Sag (3) 9,877.44 91.18 11.09 3,902.42 5,906.50 -1,884.903,841.97 6,015,342.16 549,644.36 0.39 5,984.79 3_MWD+IFR2+MS+Sag (3) 9,940.79 91.06 10.93 3,901.18 5,968.67 -1,872.803,840.73 6,015,404.41 549,656.03 0.32 6,046.36 3_MWD+IFR2+MS+Sag (3) 10,004.12 91.18 10.44 3,899.95 6,030.89 -1,861.063,839.50 6,015,466.70 549,667.34 0.80 6,108.00 3_MWD+IFR2+MS+Sag (3) 10,068.15 91.12 10.43 3,898.66 6,093.85 -1,849.463,838.21 6,015,529.74 549,678.49 0.09 6,170.38 3_MWD+IFR2+MS+Sag (3) 10,132.07 90.07 8.88 3,898.00 6,156.86 -1,838.753,837.55 6,015,592.81 549,688.78 2.93 6,232.84 3_MWD+IFR2+MS+Sag (3) 10,195.22 88.46 7.25 3,898.81 6,219.37 -1,829.893,838.36 6,015,655.38 549,697.20 3.63 6,294.90 3_MWD+IFR2+MS+Sag (3) 10,259.18 88.59 6.74 3,900.45 6,282.84 -1,822.103,840.00 6,015,718.89 549,704.55 0.82 6,357.95 3_MWD+IFR2+MS+Sag (3) 10,322.35 88.03 6.59 3,902.32 6,345.55 -1,814.773,841.87 6,015,781.65 549,711.44 0.92 6,420.28 3_MWD+IFR2+MS+Sag (3) 10,386.06 87.60 6.84 3,904.75 6,408.78 -1,807.333,844.30 6,015,844.92 549,718.45 0.78 6,483.11 3_MWD+IFR2+MS+Sag (3) 10,449.84 88.03 7.65 3,907.18 6,472.00 -1,799.293,846.73 6,015,908.19 549,726.05 1.44 6,545.91 3_MWD+IFR2+MS+Sag (3) 10,513.23 87.72 8.72 3,909.53 6,534.70 -1,790.273,849.08 6,015,970.95 549,734.63 1.76 6,608.15 3_MWD+IFR2+MS+Sag (3) 10,576.63 87.29 9.31 3,912.29 6,597.26 -1,780.353,851.84 6,016,033.56 549,744.12 1.15 6,670.20 3_MWD+IFR2+MS+Sag (3) 10,640.76 88.40 10.39 3,914.70 6,660.40 -1,769.383,854.25 6,016,096.77 549,754.65 2.41 6,732.78 3_MWD+IFR2+MS+Sag (3) 10,703.94 89.39 10.93 3,915.92 6,722.48 -1,757.703,855.47 6,016,158.92 549,765.90 1.78 6,794.27 3_MWD+IFR2+MS+Sag (3) 10,767.94 89.39 11.30 3,916.60 6,785.27 -1,745.363,856.15 6,016,221.79 549,777.80 0.58 6,856.46 3_MWD+IFR2+MS+Sag (3) 10,831.32 88.71 11.40 3,917.65 6,847.40 -1,732.893,857.20 6,016,284.00 549,789.84 1.08 6,917.97 3_MWD+IFR2+MS+Sag (3) 10,894.91 88.59 11.77 3,919.15 6,909.68 -1,720.123,858.70 6,016,346.36 549,802.18 0.61 6,979.61 3_MWD+IFR2+MS+Sag (3) 7/15/2020 4:40:39PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Definitive Survey Report Well: Wellbore: MPU I-37i MPU I-37PB1 Survey Calculation Method:Minimum Curvature MPU I-37 Actual RKB @ 60.45usft Design:MPU I-37PB1 Database:NORTH US + CANADA MD Reference:MPU I-37 Actual RKB @ 60.45usft North Reference: Well MPU I-37i 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 10,959.03 89.58 12.53 3,920.17 6,972.35 -1,706.633,859.72 6,016,409.12 549,815.24 1.95 7,041.62 3_MWD+IFR2+MS+Sag (3) 11,022.67 90.38 13.88 3,920.19 7,034.31 -1,692.093,859.74 6,016,471.17 549,829.34 2.47 7,102.87 3_MWD+IFR2+MS+Sag (3) 11,085.64 91.06 14.97 3,919.40 7,095.29 -1,676.413,858.95 6,016,532.25 549,844.61 2.04 7,163.09 3_MWD+IFR2+MS+Sag (3) 11,149.71 91.61 15.63 3,917.91 7,157.07 -1,659.513,857.46 6,016,594.14 549,861.08 1.34 7,224.05 3_MWD+IFR2+MS+Sag (3) 11,213.65 91.55 13.99 3,916.15 7,218.86 -1,643.173,855.70 6,016,656.04 549,876.99 2.57 7,285.05 3_MWD+IFR2+MS+Sag (3) 11,276.00 91.68 13.09 3,914.39 7,279.45 -1,628.583,853.94 6,016,716.72 549,891.16 1.46 7,344.93 3_MWD+IFR2+MS+Sag (3) 11,339.50 90.68 12.68 3,913.08 7,341.34 -1,614.423,852.63 6,016,778.70 549,904.88 1.70 7,406.12 3_MWD+IFR2+MS+Sag (3) 11,403.85 89.88 11.46 3,912.77 7,404.26 -1,600.973,852.32 6,016,841.71 549,917.90 2.27 7,468.38 3_MWD+IFR2+MS+Sag (3) 11,467.78 89.76 11.71 3,912.97 7,466.89 -1,588.133,852.52 6,016,904.42 549,930.31 0.43 7,530.37 3_MWD+IFR2+MS+Sag (3) 11,531.07 90.87 13.27 3,912.62 7,528.68 -1,574.443,852.17 6,016,966.29 549,943.57 3.03 7,591.49 3_MWD+IFR2+MS+Sag (3) 11,594.75 90.93 13.27 3,911.62 7,590.65 -1,559.833,851.17 6,017,028.36 549,957.75 0.09 7,652.75 3_MWD+IFR2+MS+Sag (3) 11,658.27 90.50 13.43 3,910.83 7,652.45 -1,545.163,850.38 6,017,090.25 549,971.99 0.72 7,713.83 3_MWD+IFR2+MS+Sag (3) 11,721.72 89.14 12.22 3,911.03 7,714.32 -1,531.083,850.58 6,017,152.21 549,985.64 2.87 7,775.00 3_MWD+IFR2+MS+Sag (3) 11,785.08 88.53 11.67 3,912.32 7,776.29 -1,517.963,851.87 6,017,214.26 549,998.32 1.30 7,836.33 3_MWD+IFR2+MS+Sag (3) 11,849.06 87.16 11.64 3,914.72 7,838.90 -1,505.053,854.27 6,017,276.96 550,010.80 2.14 7,898.31 3_MWD+IFR2+MS+Sag (3) 11,912.56 86.67 10.77 3,918.14 7,901.10 -1,492.733,857.69 6,017,339.24 550,022.69 1.57 7,959.89 3_MWD+IFR2+MS+Sag (3) 11,976.11 88.41 14.52 3,920.87 7,963.04 -1,478.833,860.42 6,017,401.26 550,036.16 6.50 8,021.15 3_MWD+IFR2+MS+Sag (3) 12,038.90 88.16 16.72 3,922.75 8,023.48 -1,461.933,862.30 6,017,461.81 550,052.64 3.52 8,080.77 3_MWD+IFR2+MS+Sag (3) 12,102.78 88.41 20.73 3,924.66 8,083.94 -1,441.443,864.21 6,017,522.41 550,072.71 6.29 8,140.26 3_MWD+IFR2+MS+Sag (3) 12,167.23 86.05 19.10 3,927.77 8,144.46 -1,419.513,867.32 6,017,583.07 550,094.22 4.45 8,199.73 3_MWD+IFR2+MS+Sag (3) 12,230.74 84.63 17.83 3,932.93 8,204.50 -1,399.463,872.48 6,017,643.24 550,113.85 3.00 8,258.82 3_MWD+IFR2+MS+Sag (3) 12,294.14 84.50 16.05 3,938.94 8,264.87 -1,381.083,878.49 6,017,703.73 550,131.82 2.80 8,318.31 3_MWD+IFR2+MS+Sag (3) 12,357.67 84.13 14.42 3,945.23 8,325.86 -1,364.463,884.78 6,017,764.83 550,148.01 2.62 8,378.50 3_MWD+IFR2+MS+Sag (3) 12,420.71 84.26 12.57 3,951.61 8,386.85 -1,349.833,891.16 6,017,825.91 550,162.22 2.93 8,438.77 3_MWD+IFR2+MS+Sag (3) 12,484.68 84.38 10.34 3,957.94 8,449.23 -1,337.193,897.49 6,017,888.37 550,174.43 3.47 8,500.53 3_MWD+IFR2+MS+Sag (3) 12,547.86 83.83 8.93 3,964.43 8,511.19 -1,326.673,903.98 6,017,950.40 550,184.51 2.38 8,561.95 3_MWD+IFR2+MS+Sag (3) 12,612.57 83.44 9.50 3,971.61 8,574.67 -1,316.373,911.16 6,018,013.94 550,194.37 1.06 8,624.91 3_MWD+IFR2+MS+Sag (3) 12,676.15 84.68 9.79 3,978.18 8,637.01 -1,305.773,917.73 6,018,076.35 550,204.54 2.00 8,686.72 3_MWD+IFR2+MS+Sag (3) 12,738.99 85.92 9.02 3,983.33 8,698.80 -1,295.543,922.88 6,018,138.20 550,214.34 2.32 8,747.98 3_MWD+IFR2+MS+Sag (3) 12,809.00 85.92 9.02 3,988.31 8,767.77 -1,284.593,927.86 6,018,207.24 550,224.81 0.00 8,816.39 PROJECTED to TD Approved By:Checked By:Date: 7/15/2020 4:40:39PM COMPASS 5000.15 Build 91E Page 7 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.07.15 13:46:11 -08'00' Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.07.15 13:49:46 -08'00' 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-37 Hilcorp Alaska, LLC Permit to Drill Number: 220-055 Surface Location: 2334’ FSL, 3801’ FEL, Sec. 33, T13N, R10E, UM, AK Bottomhole Location: 1669’ FNL, 981’ FWL, Sec. 21, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill 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 June, 2020. J M P i 29 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: 15,963' TVD: 4,034' 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): 58.7 15. Distance to Nearest Well Open Surface: x-551569 y- 6009449 Zone-4 32.2 to Same Pool: 15' to MPU J-25 16. Deviated wells:Kickoff depth: 320 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD Cond 20" 129.5 X-56 Weld 107' Surface Surface 107' 107' 9-5/8" 47# L-80 TXP 2,000' Surface Surface 2,000' 1,923' 9-5/8" 40# L-80 TXP 3,495' 2,000' 1,923' 5,495' 3,774' 8-1/2" 4-1/2" 13.5# L-80 Hydril 625 10,618' 5,345' 3,759' 15,963' 4,034' Tieback 3-1/2" 9.3 L-80 EUE 8Rd 5,345' Surface Surface 5,345' 3,759' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD 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- 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 3894' to nearest unit boundary 6/28/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Joe Engel jengel@hilcorp.com 777-8395 18. Casing Program:Top - Setting Depth - BottomSpecifications MPU I-37 Milne Point Field Schrader Bluff Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 2334' FSL, 3801' FEL, Sec 33, T13N, R10E, UM, AK ADL025906, ADL025517, ADL315848 022224484 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Stg 2 L - 1937 ft3 / T - 314 ft3 1283 1386' FNL, 796' FEL, Sec 32, T13N, R10E, UM, AK 1669' FNL, 981' FWL, Sec 21, T13N, R10E, UM, AK LONS 88-004 6395 1775 Total Depth MD (ft):Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Driven Stg 1 L - 813 ft3 / T - 458 ft3 Effect. Depth TVD (ft): Conductor/Structural Length Cementless Liner w/ ICDs and Pkrs Tieback Assy. Casing Intermediate Surface Commission Use Only Effect. Depth MD (ft): Authorized Signature: Production Liner See cover letter for other requirements. 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. Perforation Depth TVD (ft): 12-1/4" GL / BF Elevation above MSL (ft): 6/19/2020 es N ype of W L l R L 1b S Class: os N es No s N o D s s s D 84 o : well is p G S S 20 S S S es No s No S G E S es 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) By Samantha Carlisle at 9:44 am, Jun 19, 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: 2020.06.19 09:24:45 -08'00' Monty M Myers BOPE test to 3000 psi. Annular to 2500 psi. MGR25JUN20 220-055 50-029-23682-00-00 SFD 6/22/2020 DSR-6/22/2020GR2222222225J5555UN20 6/29/2020 I J 2120 2829 32 J-05 J-07 J-06 J-09 J-09A J-08 J-08A J-10 J-11 J-12 J-13 G-15 I-08 I-06 J-21 J-17 20 J-18 J-22 J-15 I-09 4 G-14 G-17 J-26 J-26L1 J-26L2 J-25 I-17 I-17L1 I-17L2 I-14 I-14L2 I-19 I-19L1 I-16 H-18 H-18L2 I-18 WSAK 25 J-01 J-01A J-03 J-0 I-07 J-19 J-19A J-16 I-35I-36 I-37 wp05 HILCORP ALASKA LLC MILNE POINT FIELD AOR MAP I-37 Injector (Proposed) FEET 01,0002,000 POSTED WELL DATA Well Number WELL SYMBOLS Active Oil Shut In Oil INJ Well (Water Flood) P&A Oil Abandoned Injector Injector Location Producer Location Shut In INJ REMARKSWell Sybols at top of Schrader Bluff NB Sand Black dash circle = 1320' radius from NB sand in heel and toe of proposed I-37 drill well June 17, 2020 PETRA 6/17/2020 2:47:02 PM I-366-333 I-171 7L1L I-77 J-25J J-15JJ55 I-08 I-09-0 J-19A Area of Review MPI-37 SB NbPTD API WELL STATUSTop of SB NB (MD)Top of SB NB (TVD)CBL Top of Cement (MD)CBL Top of Cement (TVD)Schrader NB statusZonal Isolation197-192 50-029-22821-00-00 MPU I-08 SB Injector5427'3785'N/AN/AOpenOpen Injector200-103 50-029-22964-00-00 MPU I-09 SB Injector5854'3808'N/AN/AOpenOpen injector204-098 50-029-23212-60-00 MPU I-17 NB Prod Lateral4486'3764'N/AN/AOpenOpen to Injection Support204-099 50-029-23212-60-00 MPU I-17L1 Oba LateralN/AN/AN/AN/AN/ANot Open204-100 50-029-23212-61-00 MPU I-17L2 OA LateralN/AN/AN/AN/AN/ANot Open204-135 50-029-23218-00-00 MPU I-19 OBa lateral Shut in6691'3868'3334'2680'Not Open**Cased and Cemented**204-136 50-029-23218-60-00 MPU I-19L1 OA LateralN/AN/AN/AN/AN/ANot Open220-047 50-029-23677-00-00 MPU I-36 NB Prod Lateral5152'3813'N/AN/AOpenOpen to Injection Support194-106 50-029-22497-00-00 MPU J-08 P&A'd / Sidetracked5038' 3892' N/A N/A ClosedCmtr @ 4890', squeezed 23 bbls beneath.199-17750-029-22497-01-00 MPU J-08A**SB OB Prod Shut in 5071' 3897' 4714' 3808' ClosedNB opened beneath whipstock - isolated with packer and cement. Cement valve at 5,776' MD, pump 15 bbls, returns observed on BU TOC at TOL @ 4,714' MD.194-101 50-029-22495-00-00 MPU J-09 P&A'd / Sidetracked5454' 3902' N/A N/A ClosedCmt Rtnr @ 5,360', Could not inject beneath retainer, PT 7" to 3000psi f/ 30 min, AOGCC approval to sidetrack well. J-09 P&A'd199-114 50-029-22495-01-00 MPU J-09A OA Prod Lateral5470' 3898' 5199' 6013' Closed97sks of cement pumped with bonzai completion, packer depth 5,199', cement valve 6,013199-107 50-029-22952-00-00 MPU J-15** SB Injector Shut In6494'3944'N/AN/AOpenOpen Injector195-169 50-029-22615-00-00 MPU J-16 Kuparuk WINJ Shut in5748' 3911' 2998' 2529' ClosedCased and Cemented - 38 bbls of cement pumped thru stage collar at 4681' MD. 195-195 50-029-22607-00-00 MPU J-19 P&A'd Kuparuk6111' 3865' NA NA Closedbalanced plug from 6390' MD to 5490'MD , 5450' MD to 4500' MD, and 4290' MD to 3600' MD195-170 50-029-22607-01-00 MPU J-19A SB SI Inj - Nb/Oa/Oba5231'3875'36932860OpenOpen InjectorMPU I-36Open injectorOpen to Injection SupportNB Prod LateralOpen InjectorMPU I-08OpenOpenCould notinject beneath retainer, 199-117OpenMPU J-15**NB opened beneath whipstock - isolated with packer and cement. Open InjectorOpen Injector SB NbNB Prod LateralSB InjectorMPU I-09OpenOpen to Injection SupportSB Injector Shut InMPU I-17Cmt Rtnr @ 5,360', SB InjectorSB SI Inj - Nb/OOpenMPU J-19A195-159Open Area of Review MPI-37 SB Nb197-200 50-029-22825-00-00 MPU J-21 SB SI Prod - Oa/Oba5752' 3802' surface surface ClosedNot Open, 295 bbls cmt pumped, returns to surface through stage tool at 2112' MD198-124 50-029-22897-00-00 MPU J-22 Reservoir Abandoned5044' 3865' Surface Surface Closed5-1/2" casing (monobore) cemented with 190 bbls Coldset II and 30 bbls Class G cement to surface. OA/OB and NB perforations squeezed with 40 bbls class G and isolated above with retrainer set at 4400' MD and tested good to 1600 psi. 204-073 50-029-23207-00-00 MPU J-25** Online, producing NB4752' 3888' 2497' 2472' Open**Open to Injection** 7-5/8" production casing cemented with 59 bbls class G from 6405' MD up to 2,497' MD (est.)204-064 50-029-23205-00-00 MPU J-26** NB Prod Lateral4936' 3840' 3105' 2624' ClosedMotherbore penetrates but is closed across NB. Actual NB lateral produced outside of AOR. 7-5/8" production casing cemented with 157 bbls class G from 6405' MD up to surface casing shoe 3,105' MD (est.)204-066 50-029-23205-60-00 MPU J-26L1** Oba LateralN/AN/AN/AN/AN/ANot Open204-067 50-029-23205-61-00 MPU J-26L2** OA LateralN/AN/AN/AN/AN/ANot Open182-027 50-029-20719-00-00WEST SAK25517-25P&A'd4041' 3803' 2680' 2650' Closed7 Production casing cemented in two stages. 1st stage 300 sks class G cement from shoe at 7481'MD up to 5050'MD (est.) 2nd Stage 575 sks class G from lower DV at 4697' MD up to upper DV/surface casing shoe near 2680' MD (est.) West Sak perforations isolated below with EZSV set at 7213' with 382' of cement (tested to 1500 psi). West Sak perfs isolated above with EZ drill packer set at 4197' MD topped with 136 ft of cement tested good to 1500 psi** MPU J-08A, J-15, J-25, J-26/L1/L2 - Future P&A as a part of I-Pad redevelopment.Open to Injection** Open**Online, producing NB Future P&A MPU J-26**NB Prod Lateral MPU J-08A, J-15, J-25, J-26/L1/L2 MPU J-25** Milne Point Unit (MPU) I-37 Drilling Program Version 1 6/18/2020 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 Internal Reporting Requirements ............................................................................................. 5 6.0 Planned Wellbore Schematic ..................................................................................................... 6 7.0 Drilling / Completion Summary ................................................................................................ 7 8.0 Mandatory Regulatory Compliance / Notifications .................................................................. 8 9.0 RU and Preparatory Work ...................................................................................................... 10 10.0 NU 13-5/8” 5M Diverter Configuration .................................................................................. 11 11.0 Drill 12-1/4” Hole Section ........................................................................................................ 13 12.0 Run 9-5/8” Surface Casing ...................................................................................................... 17 13.0 Cement 9-5/8” Surface Casing ................................................................................................. 23 14.0 BOP NU and Test..................................................................................................................... 28 15.0 Drill 8-1/2” Hole Section .......................................................................................................... 29 16.0 Run 4-1/2” Injection Liner (Lower Completion) .................................................................... 34 17.0 Run 3-1/2” Tubing (Upper Completion) ................................................................................. 38 18.0 Innovation Rig Diverter Schematic ......................................................................................... 40 19.0 Innovation Rig BOP Schematic ............................................................................................... 41 20.0 Wellhead Schematic ................................................................................................................. 42 21.0 Days Vs Depth .......................................................................................................................... 43 22.0 Formation Tops & Information............................................................................................... 44 23.0 Anticipated Drilling Hazards .................................................................................................. 45 24.0 Innovation Rig Layout ............................................................................................................. 49 25.0 FIT Procedure .......................................................................................................................... 50 26.0 Innovation Rig Choke Manifold Schematic ............................................................................ 51 27.0 Casing Design ........................................................................................................................... 52 28.0 8-1/2” Hole Section MASP ....................................................................................................... 53 29.0 Spider Plot (NAD 27) (Governmental Sections) ...................................................................... 54 30.0 Surface Plat (As Staked) (NAD 27) ......................................................................................... 55 Page 2 Milne Point Unit I-37 SB Injector Drilling Procedure 1.0 Well Summary Well MPU I-37 Pad Milne Point “I” Pad Planned Completion Type 3-1/2” Injection Tubing Target Reservoir(s) Schrader Bluff Nb Sand Planned Well TD, MD / TVD 15,962’ MD / 4,033’ TVD PBTD, MD / TVD 15,952’ MD / 4,033’ TVD Surface Location (Governmental) 2334' FSL, 3801' FEL, Sec 33, T13N, R10E, UM, AK Surface Location (NAD 27) X= 551,569.9 Y= 6,009,449.4 Top of Productive Horizon (Governmental) 1386' FNL, 796' FEL, Sec 32, T13N, R10E, UM, AK TPH Location (NAD 27) X= 549,279.9 Y= 6,010,993 BHL (Governmental) 1669' FNL, 981' FWL, Sec 21, T13N, R10E, UM, AK BHL (NAD 27) X= 550,958.9 Y=6,021,280 AFE Number 2012233 AFE Drilling Days 17 days AFE Completion Days 3 days AFE Drilling Amount AFE Completion Amount AFE Facility Amount Maximum Anticipated Pressure (Surface) 1,283 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1,775 psig Work String 5”, 19.5#, S-135, DS-50 & NC 50 KB Elevation above MSL: 26.5 ft + 33.4 ft = 58.7 ft GL Elevation above MSL: 32.2 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams Page 3 Milne Point Unit I-37 SB Injector Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit I-37 SB Injector 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) Cond 20” 19.250” - - - X-52 Weld 12-1/4” 9-5/8” 8.681” 8.525” 10.625” 47 L-80 TXP 6,870 4,750 1,086 9-5/8” 8.835” 8.679” 10.625” 40 L-80 TXP 5,750 3,090 916 8-1/2” 4-1/2” 3.960” 3.795” 4.714” 13.5 L-80 H625 9,020 8,540 279 Tubing 3-1/2” 2.992” 2.897” 4.500” 9.3 L-80 TXP-SR 9,289 7,399 163 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) Surface & Production 5” 4.276” 3.25” 6.625” 19.5 S-135 GPDS50 36,100 43,100 560klb 5” 4.276” 3.25” 6.625” 19.5 S-135 NC50 31,032 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 5 Milne Point Unit I-37 SB Injector Drilling Procedure 5.0 Internal Reporting Requirements 5.1 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. 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. 5.2 Afternoon Updates x Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorp, jengel@hilcorp.com and cdinger@hilcorp.com 5.3 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. 5.4 EHS Incident Reporting x Health and Safety: Notify EHS field coordinator. x Environmental: Drilling Environmental Coordinator x Notify Drilling Manager & Drilling Engineer on all incidents x Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally x Send final “As-Run” Casing tally to mmyers@hilcorp,com jengel@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cement report x Send casing and cement report for each string of casing to mmyers@hilcorp.com jengel@hilcorp.com and cdinger@hilcorp.com 5.7 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 Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomey@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS 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 Page 6 Milne Point Unit I-37 SB Injector Drilling Procedure 6.0 Planned Wellbore Schematic Page 7 Milne Point Unit I-37 SB Injector Drilling Procedure 7.0 Drilling / Completion Summary MPU I-37 is a grassroots injector planned to be drilled in the Schrader Bluff Nb sand. I-37 is part of a multi well program targeting the Schrader Bluff sand on I-Pad The directional plan is a catenary well path build, 12-1/4” hole with 9-5/8” surface casing set into the top of the Schrader Bluff Nb sand. An 8-1/2” lateral section will then be drilled. A 4-1/2” ICD injection liner will be run in the open hole section. The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately June 28, 2020, pending rig schedule. Surface casing will be run to 5,495’ MD / 3,773’ TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. General sequence of operations: 1. MIRU Innovation to well site 2. NU & Test 13-5/8” Diverter and 16” diverter line 3. Drill 12-1/4” hole to TD of surface hole section. Run and cement 9-5/8” surface casing. 4. ND diverter, NU & test 13-5/8” x 5M BOP. 5. Drill 8-1/2” lateral to well TD. Run 4-1/2” injection liner. 6. Run 3-1/2” tubing. 7. ND BOP, NU Tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 8 Milne Point Unit I-37 SB Injector Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. 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 BOPs shall be tested at (2) week intervals during the drilling and completion of MPU I-37. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. x The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 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 or control fluid flow from the well bore, AOGCC is to be notified and we must 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”. o Ensure the diverter vent line is at least 75’ away from potential ignition sources x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. x Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivard@hilcorp.com for submission to AOGCC. x Hilcorp Alaska proposes to demonstrate isolation of the injected fluid as required under 20 AAC 25.412 (d) through cement job operational reports of a complete two stage cement job on the 9-5/8” surface casing. Planned surface cement volumes and cement returns to surface seen during both stages will indicate placement of cement in the entire surface casing annulus. A successful FIT after surface casing drill out will demonstrate isolation of injection fluid. AOGCC Regulation Variance Requests: Hilcorp Alaska LLC does not request any variances at this time. Page 9 Milne Point Unit I-37 SB Injector Drilling Procedure Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure (psi) 12 1/4” x 13-5/8” 5M CTI Annular BOP w/ 16” diverter line Function Test Only 8-1/2” x 13-5/8” x 5M Control Technology Inc Annular BOP x 13-5/8” x 5M Control Technology Inc Double Gate o Blind ram in btm cavity x Mud cross w/ 3” x 5M side outlets x 13-5/8” x 5M Control Technology 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: 250/3,000 Subsequent Tests: 250/3,000 Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit 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 Milne Point Unit I-37 SB Injector Drilling Procedure 9.0 RU and Preparatory Work 9.1 I-37 will utilize a newly set 20” conductor on I-Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4” nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and RU. 9.6 Rig mat footprint of the rig. 9.7 MIRU Innovation Rig. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4” surface hole section. Ensure mud temperatures are cool (<80qF). 9.10 Set test plug in wellhead prior to NU diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Ensure 5” liners in mud pumps. x White Star Quattro 1300 HP mud pumps are rated at 4,097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 11 Milne Point Unit I-37 SB Injector Drilling Procedure 10.0 NU 13-5/8” 5M Diverter Configuration 10.1 NU 13-5/8” CTI BOP stack in diverter configuration (Diverter Schematic attached to program). x NU 20” x 13-5/8” DSA x NU 13 5/8”, 5M diverter “T”. x NU Knife gate & 16” diverter line. x Ensure diverter RU complies with AOGCC reg 20.AAC.25.035(C). x Diverter line must be 75 ft from nearest ignition source x Place drip berm at the end of diverter line. x Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked “warning zone” is established on each side and ahead of the vent line tip. “Warning Zone” must include: x A prohibition on vehicle parking x A prohibition on ignition sources or running equipment x A prohibition on staged equipment or materials x Restriction of traffic to essential foot or vehicle traffic only. Page 12 Milne Point Unit I-37 SB Injector Drilling Procedure 10.4 Rig & Diverter Orientation: *Orientation may differ on location Page 13 Milne Point Unit I-37 SB Injector Drilling Procedure 11.0 Drill 12-1/4” Hole Section 11.1 Consider PU 12-1/4” short collar directional only BHA: x This is for surface A/C and accurate gyro surveys closer to bit x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. 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 Be sure to run a UBHO sub for wireline gyro x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5”, 19.5#, S-135 DS50 & NC50. x Run a solid float in the surface hole section. 11.2 Begin drilling out from 20” conductor at reduced flow rates to avoid broaching the conductor. 11.3 Drill 12-1/4” hole section to section to the end of build and/or until clean MWD surveys are seen, x Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 GPM. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability x Perform wireline gyros until clean MWD surveys are seen . Take MWD surveys every stand drilled. 11.4 CBU and BROOH x POOH on elevators if possible 11.5 Make up remainder of full directional and LWD BHA Page 14 Milne Point Unit I-37 SB Injector Drilling Procedure 11.6 RIH 11.7 Drill 12-1/4” hole section to section TD, in the Schrader Nb sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. x Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. x Efforts should be made to minimize dog legs in the surface hole. x Hold a safety meeting with rig crews to discuss: x Conductor broaching ops and mitigation procedures. x Well control procedures and rig evacuation x Flow rates, hole cleaning, mud cooling, etc. x Pump sweeps and maintain mud rheology to ensure effective hole cleaning. x Keep mud as cool as possible to keep from washing out permafrost. x Pump at 400-600 GPM. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. x Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen x Slow in/out of slips and while tripping to keep swab and surge pressures low x Ensure shakers are functioning properly. Check for holes in screens on connections. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. x Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). x Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. x Gas hydrates may be present on I-Pad. Historically encountered hydrates are typically around 2,100-2,400’ TVD (just below permafrost). Be prepared for hydrates: x Gas hydrates can be identified by the gas detector and a decrease in MW or ECD x Monitor returns for hydrates, checking pressurized & non-pressurized scales x Do not stop to circulate out gas hydrates – this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 FPH MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. x Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface x A/C: x There are not wells with a clearance factor < 1.0 11.8 12-1/4” hole mud program summary: x Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Page 15 Milne Point Unit I-37 SB Injector Drilling Procedure Depth Interval MW (ppg) Surface – Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells) MW can be cut once ~500’ below hydrate zone x PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, Toolpusher office, and mud loggers office. x Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. x Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. x Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 – 9.0 range with caustic soda. Daily additions of ALDACIDE G / X-CIDE 207 MUST be made to control bacterial action. x Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). System Type: 8.8 – 9.8 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Section Density Viscosity Plastic Viscosity Yield Point API FL pH Temp Surface 8.8 – 9.8 75-175 20 - 40 25-45 <10 8.5 – 9.0 70 F System Formulation: Gel + FW spud mud Product Concentration Fresh Water soda Ash AQUAGEL caustic soda BARAZAN D+ BAROID 41 PAC-L /DEXTRID LT 0.905 bbl 0.5 ppb 15 - 20 ppb 0.1 ppb (8.5 – 9.0 pH) as needed as required for 8.8 – 9.2 ppg if required for <10 FL 8.8 – 9.8 Page 16 Milne Point Unit I-37 SB Injector Drilling Procedure ALDACIDE G 0.1 ppb 11.9 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. x This is to prevent washing out directional work to land the well 11.10 RIH to bottom, proceed to BROOH to HWDP x Pump at full drill rate (400-600 GPM), and maximize rotation. x Pull slowly, 5 – 10 FPM. x Monitor well for any signs of packing off or losses. x Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. x If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.11 TOOH and LD BHA 11.12 No open hole logging program planned. Page 17 Milne Point Unit I-37 SB Injector Drilling Procedure 12.0 Run 9-5/8” Surface Casing 12.1 RU and pull wearbushing. 12.2 RU Weatherford 9-5/8” casing running equipment (CRT & Tongs) x Ensure 9-5/8” TXP x DS50 XO on rig floor and MU to FOSV. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x RU of CRT if hole conditions require. x RU a fill up tool to fill casing while running if the CRT is not used. x Ensure all casing has been drifted to 8.750” on the location prior to running. x Surface to top of ES Cementer will be 9-5/8” 47#, drift 8.525” x Be sure to count the total # of joints on the location before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths and SN’s of all components with vendor & model info. 12.3 PU shoe joint, visually verify no debris inside joint. 12.4 Continue MU & thread locking 120’ shoe track assembly consisting of: 9-5/8” Float Shoe 1 joint – 9-5/8” TXP, 2 Centralizers 10’ from each end with stop rings 1 joint – 9-5/8” TXP, 1 Centralizer mid joint with stop ring 9-5/8” Float Collar w/ Stage Cementer Bypass Baffle ‘Top Hat’ 1 joint – 9-5/8” TXP, 1 Centralizer mid joint with stop ring 9-5/8” HES Baffle Adaptor x Ensure bypass baffle is correctly installed on top of float collar. x Ensure proper operation of float equipment while picking up. x Ensure to record SN’s of all float equipment and stage tool components. This end up. Bypass Baffle Page 18 Milne Point Unit I-37 SB Injector Drilling Procedure 12.5 Float equipment and Stage tool equipment drawings: Page 19 Milne Point Unit I-37 SB Injector Drilling Procedure 12.6 Continue running 9-5/8” surface casing x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only w/ paint brush. x Centralization: Verify depth of lowest Ugnu water sand for isolation with Geologist x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. x Any packing off while running casing should be treated as a major problem. It is preferable to POOH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES-II Stage tool so that it is positioned at least 100’ TVD below the permafrost (~ 2,500’ MD). x Install centralizers over couplings on 5 joints below and 10 joints above stage tool. x Do not place tongs on ES cementer, this can cause damaged to the tool. x Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. 9-5/8”, 40#, L-80, TXP MU Torques: Casing OD Minimum Optimum Maximum 9-5/8” 18,860 ft-lbs 20,960 ft-lbs 23,060 ft-lbs 9-5/8” 47# L-80 TXP MUT: Casing OD Minimum Optimum Maximum 9-5/8” 21,440 ft-lbs 2,3820 ft-lbs 26,200 ft-lbs Depth Interval Centralization Shoe – 1000’ Above Shoe 1/joints 1000’ above Shoe – 2000’ above Shoe (Top of Ugnu) 1/ 2 joints Page 20 Milne Point Unit I-37 SB Injector Drilling Procedure Page 21 Milne Point Unit I-37 SB Injector Drilling Procedure 12.8 Continue running 9-5/8” surface casing x 9-5/8” 47# from stage cementer to surface x Centralizers: 1 centralizer every 3rd joint to 200’ from surface x Fill casing while running using fill up line on rig floor. x Use BOL 2000 thread compound. Dope pin end only with paint brush. Page 22 Milne Point Unit I-37 SB Injector Drilling Procedure 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 PU landing joint and MU to casing string. Position the casing shoe ±10’ from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold MU water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 23 Milne Point Unit I-37 SB Injector Drilling Procedure 13.0 Cement 9-5/8” Surface Casing 13.1 Hold a pre-job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. x How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. x Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. x Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. x Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses x Review test reports and ensure pump times are acceptable. x Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) – HEC rep to witness. Mix and pump cement per below calculations for the 1st stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 1st Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" Casing (4,495' - 2,500') x .0558 bpf x 1.3 = 144.7 812.5 Total Lead 144.7 812.5 12-1/4" OH x 9-5/8" Casing (5,495' - 4,495') x .0558 bpf x 1.3 = 72.5 407 9-5/8" Shoe Track 120' x .0758 bpf = 9.1 51.09 Total Tail 81.6 458LeadTail 345 sx 394 sx Page 24 Milne Point Unit I-37 SB Injector Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets “sticky”, cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. x Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5” liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: (2500’ x .0747bpf ) + (2,875’ x .0758 bpf )= 404.65 bbls 80 bbls of tuned spacer to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Lead Slurry Tail Slurry Density 12.0 lb/gal 15.8 lb/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mixed Water 13.92 gal/sk 4.98 gal/sk okay Page 25 Milne Point Unit I-37 SB Injector Drilling Procedure 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3,300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 26 Milne Point Unit I-37 SB Injector Drilling Procedure Second Stage Surface Cement Job: 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Hold pre-job safety meeting. x Minimize pump shutdowns while circulating through stage tool and keep shutdowns to 30 minutes or less. Longer shutdowns have lead to the stage tool packing off and losing circulation x If circulation is lost, slowly stage up pumps to 2000psi and gently work/stretch pipe to regain circulation. Contact drilling engineer if unable to gain circulation at 2000 psi 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) 20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1 = 28.6 161 12-1/4" OH x 9-5/8" Casing (2,000' - 110') x .0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 12-1/4" OH x 9-5/8" Casing (2,500' - 2,000') x .0558 bpf x 2 = 55.8 314 Total Tail 55.8 314LeadTail Cement Slurry Design (2nd stage cement job): Lead Slurry Tail Slurry System Permafrost L Density 10.7 lb/gal 15.8 lb/gal Yield 4.41 ft3/sk 1.17 ft3/sk Mixed Water 22.02 gal/sk 5.08 gal/sk 270 sx 439 sx Page 27 Milne Point Unit I-37 SB Injector Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500’ x .0747bpf = 186.75 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1,000 – 1,500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8” final joint. L/D cut joint. Make final cut on 9-5/8”. Dress off stump. Install 9-5/8” wellhead. If transition nipple is welded on, allow to cool as per schedule. 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 jengel@hilcorp.com and cdinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. okay Page 28 Milne Point Unit I-37 SB Injector Drilling Procedure 14.0 BOP NU and Test 14.1 ND the diverter T, 16” knife gate, 16” diverter line & NU 11” x 13-5/8” 5M casing spool. 14.2 NU 13-5/8” x 5M CTI 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 5-1/2” VBRs in top cavity, blind ram in bottom cavity. x Single ram should be dressed with 2-7/8” x 5-1/2” VBRs or 5” Solid Body Rams x NU 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 & HCR valve on choke side of mud cross. (manual valve closest to mud cross) 14.3 Run 5” BOP test plug (if not installed previously). x Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. 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 14.4 RD BOP test equipment 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.7 Set wearbushing in wellhead. 14.8 Rack back as much 5” DP in derrick as possible to be used while drilling the hole section. 14.9 Ensure 5” liners in mud pumps. 24 hour notice to AOGCC Page 29 Milne Point Unit I-37 SB Injector Drilling Procedure 15.0 Drill 8-1/2” Hole Section 15.1 MU 8-1/2” Cleanout BHA (Milltooth Bit & 1.22° PDM) 15.2 TIH with 8-1/2” cleanout BHA to stage tool. Note depth TOC tagged on morning report. Drill out stage tool or ESIPC. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 2,500 psi for 30 minutes charted. Ensure to record volume / pressure and plot on FIT graph. AOGCC reg is 50% of burst = 6870 / 2 = ~3500 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20’ of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH & LD Cleanout BHA 15.9 PU 8-1/2” directional BHA. x Ensure BHA components have been inspected previously. x Drift and caliper all components before MU. 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 Ensure MWD is RU and operational. x Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. x Drill string will be 5”, 19.5#, S-135, DS50 & NC50. x Run a ported float in the production hole section. 15.10 8-1/2” hole section mud program summary: x Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Page 30 Milne Point Unit I-37 SB Injector Drilling Procedure 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 Rheology: Keep viscosifier additions to an absolute minimum (N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning x Run the centrifuge continuously while drilling the production hole, this will help with solids removal. x Dump and dilute as necessary to keep drilled solids to an absolute minimum. x MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller’s console, Co Man office, & Toolpusher office. System Type: 8.9 – 9.5 ppg Baradrill-N drilling fluid Properties: Section Density Plastic Viscosity Yield Point Total Solids MBT HPHT Production 8.9-9.5 15-25 20-25 <10% <7 <11.0 System Formulation: Baradrill-N Product Concentration Water KCL KOH N-VIS DEXTRID LT BARACARB 5 BARACARB 25 BARACARB 50 BARACOR 700 BARASCAV D X-CIDE 207 0.955 bbl 11 ppb 0.1 ppb 1.0 – 1.5 ppb 5 ppb 4 ppb 4 ppb 2 ppb 1.0 ppb 0.5 ppb 0.015 ppb 15.11 TIH with 8-1/2” directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid Page 31 Milne Point Unit I-37 SB Injector Drilling Procedure 15.13 Begin drilling 8-1/2” hole section, on-bottom staging technique: x Tag bottom and begin drilling with 100 - 120 RPMs at bit. Allow WOB to stabilize at 5-8K. x Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations. x If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes. 15.14 Drill 8-1/2” hole section to section TD per Geologist and Drilling Engineer. x Flow Rate: 350-550 GPM, target min. AV’s 200 FPM, 385 GPM x RPM: 120+ x Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. x Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low x Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection x Monitor Torque and Drag with pumps on every 5 stands x Monitor ECD, pump pressure & hookload trends for hole cleaning indication x Surveys can be taken more frequently if deemed necessary. x Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. x Use ADR to stay in section. x Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. x Target ROP is as fast as we can clean the hole without having to backream connections x Schrader Bluff Ob Concretions: 4-6% of lateral x A/C, wells with < 1.0 clearance factor: x I-09 – Will be P&A before i-37 is drilled. The only risk will be damage to the bit x I-29 – this is a planned well there is no risk. The future i-29 wellplan will be adjusted to clear i-37 x J-08 – P&A, the only risk is damage to the bit x J-09 – P&A, the only risk is damage to the bit x J-09A – SB OA producer lateral, geologically there is no risk. x J-15 – LTSI SB Injector, will be abandoned as part of the I pad redevelopment. We will SI the well and watch for magnetic interference when drilling past. x J-22 – P&A in 2004. The only risk is damage to the bit. x J-25 – SB NB Producer, will be abandoned as part of the I pad redevelopment. We will SI the well and watch for magnetic interference when drilling past. x J-26/PB1/PB2 – SB NB Lateral. J-26 and all laterals will be SI and is planned to be abandoned as part of the I pad redevelopment. We will watch for magnetic interference when drilling past J-26. PB1 & PB2 are OH plug backs, no risk. x J-26L1 – SB OB Lateral, geologically there is no risk. J-26 and all laterals will be SI and is planned to be abandoned as part of the I pad redevelopment. Page 32 Milne Point Unit I-37 SB Injector Drilling Procedure x J-26L2 - SB OA Lateral, geologically there is no risk. J-26 and all laterals will be SI and is planned to be abandoned as part of the I pad redevelopment. 15.15 Reference: Open hole sidetracking practice: x If a known fault is coming up, put a slight “kick-off ramp” in wellbore ahead of the fault so we have a nice place to low side. x Attempt to lowside in a fast drilling interval where the wellbore is headed up. x Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approximately 30 minutes. x Time drill at 4 to 6 FPH with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 FPM AV (385+ GPM) and rotation (120+ RPM). Pump tandem sweeps if needed x Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary x Ensure mud has necessary lube % for running liner x If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum 15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 15.18 Displace 1.5 OH + Liner volume with viscosified brine. x Proposed brine blend (same as used on M-16, aiming for an 8 on the 6 rpm reading) - KCl: 7.1bbp for 2% NaCl: 60.9 ppg for 9.4 ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5 pH Busan 1060: 0.42ppb Flo-Vis Plus: 1.25 ppb x Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. x Record SO, PU weights and rotating torque to compare to pre-brine values in report. Page 33 Milne Point Unit I-37 SB Injector Drilling Procedure 15.19 BROOH with the drilling assembly to the 9-5/8” casing shoe x Circulate at full drill rate (less if losses are seen, 350 GPM). x Rotate at maximum rpm that can be sustained. x Pulling speed 5 – 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions x If backreaming operations are commenced, continue backreaming to the shoe 15.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 15.21 CBU minimum two times at 9-5/8” shoe and clean casing with high vis sweeps. 15.22 Monitor well for flow / pressure build up with MPD. Increase fluid weight if necessary x Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise 15.23 POOH and LD BHA. 15.24 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 34 Milne Point Unit I-37 SB Injector Drilling Procedure 16.0 Run 4-1/2” Injection Liner (Lower Completion) 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2” liner with ICD and swell packers, the following well control response procedure will be followed: x With ICD across the BOP: PU & MU the 5” safety joint (with 4-1/2” crossover installed on bottom, TIW valve in open position on top, 4-1/2” handling joint above TIW). This joint shall be fully MU and available prior to running the first joint of 4-1/2” liner. x With 4-1/2” solid joint across BOP: Slack off and position the 4-1/2” solid joint to MU the TIW valve. Shut in ram or annular on 4-1/2” solid joint. Close TIW valve. 16.2. Confirm VBR have been tested on 3-1/2” and 5” test joints to 250/3,000 psi. 16.3. RU 4-1/2” liner running equipment. x Ensure 4-1/2” Hydril 625 x DS-50 crossover is on rig floor and /U to FOSV. x Ensure the liner has been drifted on the deck prior to running. x Be sure to count the total # of joints on the deck before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths and SN’s of all components with vendor & model info. 16.4. Run 4-1/2” injection liner. x Use API Modified or “Best O Life 2000 AG” thread compound. Dope pin end only with paint brush. Wipe off excess. Thread compound can plug the ICDs. x Utilize a collar clamp until weight is sufficient to keep slips set properly. x Use lift nubbins and stabbing guides for the liner run. x Fill 4-1/2” liner with PST passed mud (to keep from plugging ICDs with solids) x Install ICDs and swell packers as per the Running Order (Estimate 8 evenly spaced, Operations Engineer to provide confirmation of set depths). x Do not place tongs or slips on swell packer elements or ICDs. x ICD and swell packer placement ±40’ x The ICD connection is 4-1/2”, 13.5#, L-80, Hydril 625. x Remove protective packaging on swell packers just prior to picking up x If liner length exceeds surface casing length, ensure centralizers are placed 1/joint for each joint outside of the surface shoe. This is to mitigate difference sticking risk while running inner string. x Obtain PU and SO weights of the liner before entering open hole. Record rotating torque at 10 and 20 RPM 4-1/2”, 13.5#, L-80, Hydril 625 MU Torques Casing OD Minimum Optimum Maximum Operating Torque Yield Torque 4-1/2” 8,000 ft-lbs 9,600 ft-lbs 12,800 ft-lbs 15,000 ft-lbs Page 35 Milne Point Unit I-37 SB Injector Drilling Procedure 16.6. Ensure that the liner top packer is set ~150’ MD above the 9-5/8” shoe. x AOGCC regulations require a minimum 100’ overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Ensure hanger/packer will not be set in a 9-5/8” connection. 16.7. Before picking up Baker SLZXP liner hanger/packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. Page 36 Milne Point Unit I-37 SB Injector Drilling Procedure 16.8. MU Baker SLZXP liner hanger/packer to 4-1/2” liner. 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 minutes for mixture to set up. 16.9. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH with liner on all 5” HWDP no faster than 30 FPM – this is to prevent buckling the liner and drill string. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. 16.11. The liner will prevent the DP from auto filling. Fill DP every 5 stands, more frequently if SOW trend indicates. 16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.13. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.14. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.15. Rig up to pump down the work string with the rig pumps. 16.16. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.17. Drop setting ball down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to shift the wellbore isolation valve closed. 16.18. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the ZXP to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,100 psi to neutralize and release running tools. 16.19. Bleed DP pressure to 0 psi, Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Contingency (if suspected not released from running tool) - Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 16.20. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. 16.21. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. Page 37 Milne Point Unit I-37 SB Injector Drilling Procedure 16.22. POOH laying down DP then rack back enough 5” DP for the liner top cleanout run. LD and inspect the liner running tools. Once running tools are LD, swap to the Completion AFE. 16.23. Make up 3-1/2” wash tool and RIH on 5” DP to the liner top. 16.24. Flush liner top at max rate while displacing out well to clean brine. 16.25. POOH LD remaining 5” DP. Page 38 Milne Point Unit I-37 SB Injector Drilling Procedure 17.0 Run 3-1/2” Tubing (Upper Completion) 17.1 Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivard@hilcorp.com for submission to AOGCC. 17.2 MU injection assembly and RIH to setting depth. TIH no faster than 90 FPM. x Ensure wear bushing is pulled. x Ensure 3-1/2” EUE 8rd x NC-50 crossover is on rig floor and MU to FOSV. x Ensure all tubing has been drifted in the pipe shed prior to running. x Be sure to count the total # of joints in the pipe shed before running. x Keep hole covered while RU casing tools. x Record OD’s, ID’s, lengths and SN’s of all components with vendor & model info. x Monitor displacement from wellbore while RIH. 3-1/2” Upper Completion Running Order: x 7.30” Baker Ported Bullet Nose seal (stung into the tie back receptacle, crossover to 3-1/2”, 9.3#, EUE 8rd) x 3 joints (minimum, more as needed), 3-1/2”, 9.3#, EUE 8rd tubing x 3-1/2” “XN” nipple at TBD (less than 70° hole angle) x 1 joints, 3-1/2”, 9.3#, EUE 8rd tubing x 3-1/2” Baker gauge mandrel o Cross collar clamps: Every joint for first 10 joints, every other joint beyond this to surface x XX Joints, 3-1/2”, 9.3#, EUE 8rd tubing x Space out pup(s), 3-1/2”, 9.3#, EUE 8rd tubing x 1 joint, 3-1/2”, 9.3#, EUE 8rd tubing x Tubing hanger with 3-1/2” EUE 8rd pin down 17.3 Locate and no-go out the seal assembly. Close annular and test to 500 psi to confirm seals engaged. 17.4 Bleed pressure and open annular. Space out the completion (±2’ above No-Go). Place all space out pups below the first full joint of the completion. Page 39 Milne Point Unit I-37 SB Injector Drilling Procedure 17.5 MU the tubing hanger and landing joint. 17.6 RIH. Close annular and test to 500 psi to confirm seals are engaged. Bleed pressure down to 250 psi. PU until ports in seal assembly exposed. 17.7 Reverse circulate the well with corrosion inhibited brine. 17.8 Freeze protect the IA to ~2,000’ TVD (base on actual well deviation) with diesel. 17.9 Land hanger and RILDS. 17.10 PT the IA to 2,500 psi for 30 minutes charted. i. Note this test must be witnessed by the AOGCC representative. 17.11 Set BPV, ensure new body seals are installed each time. 17.12 ND BOPE and install the plug off tool into the BPV. 17.13 NU the tubing head adapter and NU the tree. 17.14 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 17.15 Pull the plug off tool from the BPV. 17.16 Bullhead diesel down the tubing to ~2,000’ TVD (base on actual well deviation). 17.17 Install all tree gauges. Secure the tree and cellar. Release the rig. 17.18 RDMO the Innovation Rig. 17.19 Turn the well over to operations via handover form. PT the IA to 2,500 psi for 30 minutes charted. i.Note this test must be witnessed by the AOGCC representative. ** Witnessed MIT-IA after stabilized injection. Page 40 Milne Point Unit I-37 SB Injector Drilling Procedure 18.0 Innovation Rig Diverter Schematic Page 41 Milne Point Unit I-37 SB Injector Drilling Procedure 19.0 Innovation Rig BOP Schematic Page 42 Milne Point Unit I-37 SB Injector Drilling Procedure 20.0 Wellhead Schematic Page 43 Milne Point Unit I-37 SB Injector Drilling Procedure 21.0 Days Vs Depth Page 44 Milne Point Unit I-37 SB Injector Drilling Procedure 22.0 Formation Tops & Information MPU i-37 Formations (wp06) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 1841 -1732 1792 788.48 8.46 LA3 4040 -3213 3273 1440.12 8.46 Ugnu MB 4485 -3447 3507 1543.08 8.46 Schrader Bluff NA 5235 -3685 3745 1647.8 8.46 Schrader Bluff NB 5530 -3716 3776 1661.44 8.46 Page 45 Milne Point Unit I-37 SB Injector Drilling Procedure 23.0 Anticipated Drilling Hazards 12-1/4” Hole Section: Lost Circulation 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. Gas Hydrates Gas hyrates have been seen on E Pad. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non- pressurized scale will reflect the actual mud cut weight. Add 1.0 – 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. 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 hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are a number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Well Specific A/C: x There are no wells with a clearance factor of <1.0 Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Page 46 Milne Point Unit I-37 SB Injector Drilling Procedure Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 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 47 Milne Point Unit I-37 SB Injector Drilling Procedure 8-1/2” Hole Section: 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 of > 300 gpm Lost Circulation: 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. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a “ramp” in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we’ll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 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. Abnormal Pressures and Temperatures: Abnormal pressure has been seen on E-Pad. Utilize MPD to mitigate any abnormal pressure seen. Anti-Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. x A/C, wells with < 1.0 clearance factor: x I-09 – Will be P&A before i-37 is drilled. The only risk will be damage to the bit x I-29 – this is a planned well there is no risk. The future i-29 wellplan will be adjusted to clear i-37 x J-08 – P&A, the only risk is damage to the bit x J-09 – P&A, the only risk is damage to the bit Anti-Collision Page 48 Milne Point Unit I-37 SB Injector Drilling Procedure x J-09A – SB OA producer lateral, geologically there is no risk. x J-15 – LTSI SB Injector, will be abandoned as part of the I pad redevelopment. We will SI the well and watch for magnetic interference when drilling past. x J-22 – P&A in 2004. The only risk is damage to the bit. x J-25 – SB NB Producer, will be abandoned as part of the I pad redevelopment. We will SI the well and watch for magnetic interference when drilling past. x J-26/PB1/PB2 – SB NB Lateral. J-26 and all laterals will be SI and is planned to be abandoned as part of the I pad redevelopment. We will watch for magnetic interference when drilling past J-26. PB1 & PB2 are OH plug backs, no risk. x J-26L1 – SB OB Lateral, geologically there is no risk. J-26 and all laterals will be SI and is planned to be abandoned as part of the I pad redevelopment. x J-26L2 - SB OA Lateral, geologically there is no risk. J-26 and all laterals will be SI and is planned to be abandoned as part of the I pad redevelopment. Page 49 Milne Point Unit I-37 SB Injector Drilling Procedure 24.0 Innovation Rig Layout Page 50 Milne Point Unit I-37 SB Injector Drilling Procedure 25.0 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. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 51 Milne Point Unit I-37 SB Injector Drilling Procedure 26.0 Innovation Rig Choke Manifold Schematic Page 52 Milne Point Unit I-37 SB Injector Drilling Procedure 27.0 Casing Design 12-1/4"Mud Density:9.2 ppg 8-1/2"Mud Density:9.2 ppg Mud Density: 1283 psi (see attached MASP determination & calculation) 1283 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress 1234 9-5/8"4-1/2" 0 5,494 0 3,773 5,494 15,962 3,773 4,033 5,494 10,468 40 13.5 L-80 L-80 TXP H625 219,760 141,318 219,760 141,318 916 307 4.17 2.17 1,864 1,992 3,090 8,540 1.66 4.29 1,283 1,283 5,750 9,020 4.48 7.03Worst case safety factor (Burst) MASP: Production Mode Minimum Yield (psi) Weight (ppf) MASP (psi) Worst Case Safety Factor (Tension) Collapse Pressure at bottom (Psi) Worst Case Safety Factor (Collapse) Length Calculation & Casing Design Factors Calculation/Specification Casing OD Bottom (MD) Bottom (TVD) Top (MD) MASP: Drilling Mode MASP: Hole Size DATE: 6/16/2020 WELL: MPU I-37 DESIGN BY: Joe Engel Hole Size Hole Size Casing Section Design Criteria: Collapse Resistance w/o tension (Psi) Top (TVD) Tension at Top of Section (lbs) Grade Connection Weight w/o Bouyancy Factor (lbs) Min strength Tension (1000 lbs) 4.17 2.17 1,864 1,992 4.48 7.03 1.66 4.29 1,283 1,283 Page 53 Milne Point Unit I-37 SB Injector Drilling Procedure 28.0 8-1/2” Hole Section MASP MD TVD Planned Top: 5495 3773 Planned TD: 15962 4033 Anticipated Formations and Pressures: Formation Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff NB Sand 1775 Oil 8.46 0.440 Offset Well Mud Densities Well Sand MW range Top (TVD) Bottom (TVD) Date i-35 SB NB 8.9 - 9.1 Surface 4001 2020 i-36 SB NB 8.9 - 9.3 Surface 3958 2020 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 3773 (ft) x 0.78(psi/ft)= 2943 2943(psi) - [0.1(psi/ft)*3773(ft)]= 2566 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff sand) 3773 (ft) x 0.44(psi/ft)= 1660 psi 1660(psi) - 0.1(psi/ft)*3773(ft) 1283 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Maximum Anticipated Surface Pressure Calculation 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 8-1/2" Hole Section MPU I-37 Milne Point Unit TVD 4,033 3773 (ft) x 0.44(psi/ft)= 1660 psi 1660(psi) - 0.1(psi/ft)*3773(ft)1283 psi i Page 54 Milne Point Unit I-37 SB Injector Drilling Procedure 29.0 Spider Plot (NAD 27) (Governmental Sections) Page 55 Milne Point Unit I-37 SB Injector Drilling Procedure 30.0 Surface Plat (As Staked) (NAD 27) 16 June, 2020 Plan: MPU I-37 wp06 Milne Point M Pt I Pad Plan: MPU I-37i MPU I-37i 0750150022503000375045005250True Vertical Depth (1500 usft/in)-750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250Vertical Section at 357.44° (1500 usft/in)MPI-Richmond wp02 CP1MPI-Richmond wp02 CP2MPI-Richmond wp06 HeelMPI-Richmond wp02 CP3MPI-Richmond wp05 CP4MPI-Richmond wp05 Toe9 5/8" x 12 1/4"4 1/2" x 8 1/2"5001000150020002500300035004000450050005500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 15963MPU I-37 wp06Start Dir 3º/100' : 320' MD, 320'TVDEnd Dir : 579.33' MD, 578.82' TVDStart Dir 3º/100' : 850' MD, 848.46'TVDEnd Dir : 1084.41' MD, 1080.16' TVDStart Dir 3º/100' : 1200' MD, 1193.23'TVDStart Dir 4º/100' : 1368.08' MD, 1357.43'TVDEnd Dir : 2356.67' MD, 2175.6' TVDStartDir4º/100':3286.34'MD, 2791.7'TVDEndDir :5395.39' MD, 3764.98'TVDStartDir3º/100':5495.39'MD, 3773.7'TVDEndDir :5630.61' MD, 3780.71'TVDStartDir3º/100':7272.12'MD, 3807.74'TVDEndDir :7465.36' MD, 3809.78'TVDStartDir3º/100':8325.98'MD, 3817.26'TVDEndDir : 8415.69' MD, 3818.7'TVDStartDir3º/100':10540.35'MD,3868.07'TVDEndDir :10638.9' MD, 3870.06'TVDStartDir3º/100':14130'MD, 3938.69'TVDEndDir : 14289.77' MD, 3944.52'TVDTotal Depth:15962.73'MD,4033.7'TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Pedal CurveWarning Method: Error RatioWELL DETAILS: Plan: MPU I-37i32.20+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006009449.42551569.97 70° 26' 11.632 N 149° 34' 46.348 WSURVEY PROGRAMDate: 2020-06-16T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 800.00 MPU I-37 wp06 (MPU I-37i) 3_Gyro-GC_Csg800.00 5495.39 MPU I-37 wp06 (MPU I-37i) 3_MWD+IFR2+MS+Sag5495.39 15962.73 MPU I-37 wp06 (MPU I-37i) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-37i, True NorthVertical (TVD) Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Measured Depth Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Calculation Method:Minimum CurvatureProject:Milne PointSite:M Pt I PadWell:Plan: MPU I-37iWellbore:MPU I-37iDesign:MPU I-37 wp06CASING DETAILSTVD TVDSS MD SizeName3773.70 3715.00 5495.39 9-5/8 9 5/8" x 12 1/4"4033.70 3975.00 15962.73 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.002 320.00 0.00 0.00 320.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 320' MD, 320'TVD3 470.00 4.50 340.00 469.85 5.53 -2.01 3.00 340.00 5.624 579.33 5.00 300.00 578.82 11.95 -7.61 3.00 -101.70 12.27 End Dir : 579.33' MD, 578.82' TVD5 850.00 5.00 300.00 848.46 23.74 -28.04 0.00 0.00 24.97 Start Dir 3º/100' : 850' MD, 848.46'TVD6 1084.41 12.00 295.00 1080.16 39.17 -59.01 3.00 -8.51 41.76 End Dir : 1084.41' MD, 1080.16' TVD7 1200.00 12.00 295.00 1193.23 49.32 -80.79 0.00 0.00 52.88 Start Dir 3º/100' : 1200' MD, 1193.23'TVD8 1368.08 13.00 272.00 1357.43 57.37 -115.54 3.00 -90.03 62.48 Start Dir 4º/100' : 1368.08' MD, 1357.43'TVD9 2244.10 48.00 268.00 2100.60 49.20 -553.04 4.00 -5.18 73.8510 2356.67 48.49 274.00 2175.60 50.68 -636.93 4.00 85.71 79.08 End Dir : 2356.67' MD, 2175.6' TVD11 3286.34 48.49 274.00 2791.70 99.25 -1331.45 0.00 0.00 158.62 Start Dir 4º/100' : 3286.34' MD, 2791.7'TVD12 5395.39 85.00 0.89 3764.98 1459.92 -2281.01 4.00 91.70 1560.35 End Dir : 5395.39' MD, 3764.98' TVD13 5495.39 85.00 0.89 3773.70 1559.53 -2279.46 0.00 0.00 1659.79 MPI-Richmond wp06 Heel Start Dir 3º/100' : 5495.39' MD, 3773.7'TVD14 5630.61 89.06 0.85 3780.71 1694.52 -2277.42 3.00 -0.59 1794.56 End Dir : 5630.61' MD, 3780.71' TVD15 7272.12 89.06 0.85 3807.74 3335.63 -2253.12 0.00 0.00 3432.94 Start Dir 3º/100' : 7272.12' MD, 3807.74'TVD16 7345.10 89.46 3.00 3808.69 3408.55 -2250.67 3.00 79.39 3505.68 MPI-Richmond wp02 CP117 7465.36 89.50 6.61 3809.78 3528.37 -2240.61 3.00 89.35 3624.93 End Dir : 7465.36' MD, 3809.78' TVD18 8325.98 89.50 6.61 3817.26 4383.24 -2141.58 0.00 0.00 4474.52 Start Dir 3º/100' : 8325.98' MD, 3817.26'TVD19 8415.45 88.67 9.16 3818.69 4471.84 -2129.31 3.00 108.07 4562.49 MPI-Richmond wp02 CP2 End Dir : 8415.69' MD, 3818.7' TVD20 8415.69 88.67 9.15 3818.70 4472.08 -2129.27 3.00 -101.92 4562.73 End Dir : 8415.69' MD, 3818.7' TVD21 10540.35 88.67 9.15 3868.07 6569.12 -1791.39 0.00 0.00 6642.58 Start Dir 3º/100' : 10540.35' MD, 3868.07'TVD22 10569.37 88.87 10.00 3868.69 6597.73 -1786.57 3.00 76.63 6670.95 MPI-Richmond wp02 CP323 10638.90 88.87 12.09 3870.06 6665.96 -1773.25 3.00 89.92 6738.51 End Dir : 10638.9' MD, 3870.06' TVD24 14130.00 88.87 12.09 3938.69 10079.01 -1042.41 0.00 0.00 10115.51 MPI-Richmond wp05 CP4 Start Dir 3º/100' : 14130' MD, 3938.69'TVD25 14289.77 86.94 16.48 3944.52 10233.69 -1003.04 3.00 113.80 10268.28 End Dir : 14289.77' MD, 3944.52' TVD26 15962.73 86.94 16.48 4033.70 11835.67 -529.20 0.00 0.00 11847.49 MPI-Richmond wp05 Toe Total Depth : 15962.73' MD, 4033.7' TVD 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 South(-)/North(+) (1500 usft/in)-6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 West(-)/East(+) (1500 usft/in) MPI-Richmond wp05 Toe MPI-Richmond wp05 CP4 MPI-Richmond wp02 CP3 MPI-Richmond wp06 Heel MPI-Richmond wp02 CP2 MPI-Richmond wp02 CP1 9 5/8" x 12 1/4" 4 1/2" x 8 1/2"1500175022502750325035 00 37 5 0 4000 4034 MPUI-37wp06 Start Dir 3º/100' : 320' MD, 320'TVD End Dir : 579.33' MD, 578.82' TVD Start Dir 3º/100' : 850' MD, 848.46'TVD End Dir : 1084.41' MD, 1080.16' TVD Start Dir 4º/100' : 1368.08' MD, 1357.43'TVD Start Dir 4º/100' : 3286.34' MD, 2791.7'TVD End Dir : 5395.39' MD, 3764.98' TVD Start Dir 3º/100' : 5495.39' MD, 3773.7'TVD End Dir : 5630.61' MD, 3780.71' TVD Start Dir 3º/100' : 7272.12' MD, 3807.74'TVD End Dir : 7465.36' MD, 3809.78' TVD Start Dir 3º/100' : 8325.98' MD, 3817.26'TVD End Dir : 8415.69' MD, 3818.7' TVD Start Dir 3º/100' : 10540.35' MD, 3868.07'TVD End Dir : 10638.9' MD, 3870.06' TVD Start Dir 3º/100' : 14130' MD, 3938.69'TVD End Dir : 14289.77' MD, 3944.52' TVD Total Depth : 15962.73' MD, 4033.7' TVD CASING DETAILS TVD TVDSS MD Size Name 3773.70 3715.00 5495.39 9-5/8 9 5/8" x 12 1/4" 4033.70 3975.00 15962.73 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt I Pad Well: Plan: MPU I-37i Wellbore: MPU I-37i Plan: MPU I-37 wp06 WELL DETAILS: Plan: MPU I-37i 32.20 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 6009449.42 551569.97 70° 26' 11.632 N 149° 34' 46.348 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU I-37i, True North Vertical (TVD) Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev) Measured Depth Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev) Calculation Method:Minimum Curvature Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i 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 I Pad, TR-13-10 usft Map usft usft °0.39Slot Radius:"0 6,008,388.01 550,245.83 0.00 70° 26' 1.282 N 149° 35' 25.422 W Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Plan: MPU I-37i, Slot 30 usft usft 0.00 0.00 6,009,449.42 551,569.97 32.20Wellhead Elevation:usft0.50 70° 26' 11.632 N 149° 34' 46.348 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-37i Model NameMagnetics BGGM2020 8/16/2020 15.89 80.83 57,370.18108019 Phase:Version: Audit Notes: Design MPU I-37 wp06 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.50 357.440.000.0026.50 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i True 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 0.000.000.000.000.000.0026.500.000.0026.50 -32.20 0.000.000.000.000.000.00320.000.000.00320.00 261.30 340.000.003.003.00-2.015.53469.85340.004.50470.00 411.15 -101.70-36.590.463.00-7.6111.95578.82300.005.00579.33 520.12 0.000.000.000.00-28.0423.74848.46300.005.00850.00 789.76 -8.51-2.132.993.00-59.0139.171,080.16295.0012.001,084.41 1,021.46 0.000.000.000.00-80.7949.321,193.23295.0012.001,200.00 1,134.53 -90.03-13.680.593.00-115.5457.371,357.43272.0013.001,368.08 1,298.73 -5.18-0.464.004.00-553.0449.202,100.60268.0048.002,244.10 2,041.90 85.715.330.444.00-636.9350.682,175.60274.0048.492,356.67 2,116.90 0.000.000.000.00-1,331.4599.252,791.70274.0048.493,286.34 2,733.00 91.704.121.734.00-2,281.011,459.923,764.980.8985.005,395.39 3,706.28 0.000.000.000.00-2,279.461,559.533,773.700.8985.005,495.39 3,715.00 -0.59-0.033.003.00-2,277.421,694.523,780.710.8589.065,630.61 3,722.01 0.000.000.000.00-2,253.123,335.633,807.740.8589.067,272.12 3,749.04 79.392.950.553.00-2,250.673,408.553,808.693.0089.467,345.10 3,749.99 89.353.000.033.00-2,240.613,528.373,809.786.6189.507,465.36 3,751.08 0.000.000.000.00-2,141.584,383.243,817.266.6189.508,325.98 3,758.56 108.072.85-0.933.00-2,129.314,471.843,818.699.1688.678,415.45 3,759.99 -101.92-2.94-0.623.00-2,129.274,472.083,818.709.1588.678,415.69 3,760.00 0.000.000.000.00-1,791.396,569.123,868.079.1588.6710,540.35 3,809.37 76.632.920.693.00-1,786.576,597.733,868.6910.0088.8710,569.37 3,809.99 89.923.000.013.00-1,773.256,665.963,870.0612.0988.8710,638.90 3,811.36 0.000.000.000.00-1,042.4110,079.013,938.6912.0988.8714,130.00 3,879.99 113.802.75-1.213.00-1,003.0410,233.693,944.5216.4886.9414,289.77 3,885.82 0.000.000.000.00-529.2011,835.674,033.7016.4886.9415,962.73 3,975.00 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i 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 -32.20 Vert Section 26.50 0.00 26.50 0.00 0.000.00 551,569.976,009,449.42-32.20 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 551,569.976,009,449.4241.30 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 551,569.976,009,449.42141.30 0.00 0.00 300.00 0.00 300.00 0.00 0.000.00 551,569.976,009,449.42241.30 0.00 0.00 320.00 0.00 320.00 0.00 0.000.00 551,569.976,009,449.42261.30 0.00 0.00 Start Dir 3º/100' : 320' MD, 320'TVD 400.00 2.40 399.98 1.57 -0.57340.00 551,569.396,009,450.99341.28 3.00 1.60 470.00 4.50 469.85 5.53 -2.01340.00 551,567.926,009,454.94411.15 3.00 5.62 500.00 4.41 499.76 7.62 -3.02328.45 551,566.906,009,457.02441.06 3.00 7.75 579.33 5.00 578.83 11.95 -7.61300.00 551,562.286,009,461.31520.13 3.00 12.27 End Dir : 579.33' MD, 578.82' TVD 600.00 5.00 599.42 12.85 -9.17300.00 551,560.716,009,462.20540.72 0.00 13.24 700.00 5.00 699.04 17.21 -16.72300.00 551,553.146,009,466.51640.34 0.00 17.93 800.00 5.00 798.66 21.56 -24.26300.00 551,545.566,009,470.81739.96 0.00 22.63 850.00 5.00 848.47 23.74 -28.04300.00 551,541.776,009,472.97789.77 0.00 24.97 Start Dir 3º/100' : 850' MD, 848.46'TVD 900.00 6.49 898.22 26.16 -32.42298.03 551,537.376,009,475.35839.52 3.00 27.58 1,000.00 9.47 997.24 32.42 -44.81295.95 551,524.946,009,481.52938.54 3.00 34.39 1,084.41 12.00 1,080.16 39.17 -59.01295.00 551,510.706,009,488.171,021.46 3.00 41.76 End Dir : 1084.41' MD, 1080.16' TVD 1,100.00 12.00 1,095.41 40.54 -61.95295.00 551,507.756,009,489.521,036.71 0.00 43.26 1,200.00 12.00 1,193.23 49.32 -80.79295.00 551,488.856,009,498.181,134.53 0.00 52.88 Start Dir 3º/100' : 1200' MD, 1193.23'TVD 1,300.00 12.36 1,291.00 55.73 -100.73280.85 551,468.876,009,504.451,232.30 3.00 60.18 1,368.08 13.00 1,357.42 57.37 -115.54272.00 551,454.056,009,505.991,298.72 3.00 62.48 Start Dir 4º/100' : 1368.08' MD, 1357.43'TVD 1,400.00 14.27 1,388.44 57.60 -123.06271.53 551,446.526,009,506.171,329.74 4.00 63.04 1,500.00 18.26 1,484.42 58.07 -151.06270.48 551,418.526,009,506.431,425.72 4.00 64.76 1,600.00 22.25 1,578.22 58.13 -185.68269.80 551,383.916,009,506.261,519.52 4.00 66.37 1,700.00 26.25 1,669.37 57.80 -226.74269.31 551,342.856,009,505.641,610.67 4.00 67.87 1,800.00 30.25 1,757.45 57.07 -274.06268.95 551,295.556,009,504.591,698.75 4.00 69.25 1,900.00 34.24 1,842.01 55.95 -327.39268.66 551,242.246,009,503.101,783.31 4.00 70.52 2,000.00 38.24 1,922.64 54.44 -386.47268.43 551,183.176,009,501.191,863.94 4.00 71.65 2,100.00 42.24 1,998.96 52.56 -451.03268.23 551,118.636,009,498.861,940.26 4.00 72.65 2,200.00 46.24 2,070.59 50.30 -520.75268.07 551,048.946,009,496.122,011.89 4.00 73.52 2,244.10 48.00 2,100.60 49.20 -553.04268.00 551,016.666,009,494.792,041.90 4.00 73.85 2,300.00 48.21 2,137.94 48.83 -594.64270.99 550,975.076,009,494.132,079.24 4.00 75.34 2,356.67 48.49 2,175.60 50.68 -636.93274.00 550,932.766,009,495.692,116.90 4.00 79.08 End Dir : 2356.67' MD, 2175.6' TVD 2,400.00 48.49 2,204.32 52.94 -669.30274.00 550,900.386,009,497.732,145.62 0.00 82.78 2,500.00 48.49 2,270.59 58.17 -744.01274.00 550,825.656,009,502.432,211.89 0.00 91.34 2,600.00 48.49 2,336.86 63.39 -818.71274.00 550,750.926,009,507.142,278.16 0.00 99.90 2,700.00 48.49 2,403.13 68.62 -893.42274.00 550,676.186,009,511.852,344.43 0.00 108.45 2,800.00 48.49 2,469.40 73.84 -968.13274.00 550,601.456,009,516.562,410.70 0.00 117.01 2,900.00 48.49 2,535.67 79.06 -1,042.83274.00 550,526.726,009,521.262,476.97 0.00 125.57 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i 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 2,543.24 Vert Section 3,000.00 48.49 2,601.94 84.29 -1,117.54274.00 550,451.996,009,525.972,543.24 0.00 134.12 3,100.00 48.49 2,668.21 89.51 -1,192.24274.00 550,377.256,009,530.682,609.51 0.00 142.68 3,200.00 48.49 2,734.48 94.74 -1,266.95274.00 550,302.526,009,535.392,675.78 0.00 151.24 3,286.34 48.49 2,791.70 99.25 -1,331.45274.00 550,238.006,009,539.452,733.00 0.00 158.62 Start Dir 4º/100' : 3286.34' MD, 2791.7'TVD 3,300.00 48.48 2,800.75 100.03 -1,341.65274.73 550,227.796,009,540.162,742.05 4.00 159.86 3,400.00 48.52 2,867.04 109.67 -1,415.87280.07 550,153.516,009,549.292,808.34 4.00 172.80 3,500.00 48.80 2,933.12 126.21 -1,489.05285.39 550,080.226,009,565.322,874.42 4.00 192.60 3,600.00 49.33 2,998.66 149.57 -1,560.85290.64 550,008.286,009,588.182,939.96 4.00 219.14 3,700.00 50.09 3,063.35 179.63 -1,630.90295.78 549,938.026,009,617.753,004.65 4.00 252.30 3,800.00 51.07 3,126.87 216.24 -1,698.87300.80 549,869.816,009,653.893,068.17 4.00 291.91 3,900.00 52.26 3,188.92 259.24 -1,764.43305.67 549,803.966,009,696.433,130.22 4.00 337.80 4,000.00 53.65 3,249.18 308.41 -1,827.26310.38 549,740.806,009,745.163,190.48 4.00 389.72 4,100.00 55.21 3,307.37 363.50 -1,887.05314.90 549,680.646,009,799.833,248.67 4.00 447.43 4,200.00 56.93 3,363.20 424.26 -1,943.50319.25 549,623.776,009,860.193,304.50 4.00 510.65 4,300.00 58.80 3,416.40 490.39 -1,996.36323.43 549,570.476,009,925.943,357.70 4.00 579.07 4,400.00 60.80 3,466.71 561.55 -2,045.35327.44 549,520.996,009,996.763,408.01 4.00 652.35 4,500.00 62.91 3,513.89 637.42 -2,090.23331.29 549,475.586,010,072.313,455.19 4.00 730.15 4,600.00 65.13 3,557.70 717.61 -2,130.80335.00 549,434.466,010,152.213,499.00 4.00 812.07 4,700.00 67.43 3,597.94 801.73 -2,166.85338.57 549,397.836,010,236.073,539.24 4.00 897.72 4,800.00 69.81 3,634.40 889.39 -2,198.21342.03 549,365.876,010,323.503,575.70 4.00 986.69 4,900.00 72.25 3,666.91 980.14 -2,224.72345.38 549,338.746,010,414.063,608.21 4.00 1,078.53 5,000.00 74.75 3,695.32 1,073.55 -2,246.26348.63 549,316.566,010,507.313,636.62 4.00 1,172.81 5,100.00 77.30 3,719.47 1,169.16 -2,262.72351.82 549,299.446,010,602.793,660.77 4.00 1,269.06 5,200.00 79.88 3,739.26 1,266.51 -2,274.02354.93 549,287.476,010,700.053,680.56 4.00 1,366.82 5,300.00 82.49 3,754.59 1,365.12 -2,280.10358.00 549,280.716,010,798.613,695.89 4.00 1,465.60 5,395.39 85.00 3,764.98 1,459.92 -2,281.010.89 549,279.146,010,893.393,706.28 4.00 1,560.35 End Dir : 5395.39' MD, 3764.98' TVD 5,400.00 85.00 3,765.39 1,464.51 -2,280.940.89 549,279.186,010,897.983,706.69 0.00 1,564.93 5,495.39 85.00 3,773.70 1,559.52 -2,279.460.89 549,280.006,010,993.003,715.00 0.00 1,659.79 Start Dir 3º/100' : 5495.39' MD, 3773.7'TVD - 9 5/8" x 12 1/4" 5,500.00 85.14 3,774.10 1,564.12 -2,279.390.89 549,280.046,010,997.593,715.40 3.00 1,664.37 5,600.00 88.14 3,779.96 1,663.92 -2,277.870.86 549,280.876,011,097.393,721.26 3.00 1,764.01 5,630.61 89.06 3,780.71 1,694.52 -2,277.420.85 549,281.116,011,127.993,722.01 3.00 1,794.55 End Dir : 5630.61' MD, 3780.71' TVD 5,700.00 89.06 3,781.85 1,763.89 -2,276.390.85 549,281.666,011,197.363,723.15 0.00 1,863.81 5,800.00 89.06 3,783.50 1,863.87 -2,274.910.85 549,282.456,011,297.333,724.80 0.00 1,963.62 5,900.00 89.06 3,785.15 1,963.84 -2,273.430.85 549,283.246,011,397.313,726.45 0.00 2,063.43 6,000.00 89.06 3,786.79 2,063.82 -2,271.950.85 549,284.036,011,497.283,728.09 0.00 2,163.24 6,100.00 89.06 3,788.44 2,163.79 -2,270.470.85 549,284.816,011,597.253,729.74 0.00 2,263.05 6,200.00 89.06 3,790.09 2,263.77 -2,268.990.85 549,285.606,011,697.233,731.39 0.00 2,362.86 6,300.00 89.06 3,791.73 2,363.75 -2,267.510.85 549,286.396,011,797.203,733.03 0.00 2,462.67 6,400.00 89.06 3,793.38 2,463.72 -2,266.030.85 549,287.186,011,897.183,734.68 0.00 2,562.48 6,500.00 89.06 3,795.03 2,563.70 -2,264.550.85 549,287.976,011,997.153,736.33 0.00 2,662.29 6,600.00 89.06 3,796.68 2,663.67 -2,263.070.85 549,288.766,012,097.123,737.98 0.00 2,762.10 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i 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 3,739.62 Vert Section 6,700.00 89.06 3,798.32 2,763.65 -2,261.590.85 549,289.546,012,197.103,739.62 0.00 2,861.91 6,800.00 89.06 3,799.97 2,863.62 -2,260.110.85 549,290.336,012,297.073,741.27 0.00 2,961.72 6,900.00 89.06 3,801.62 2,963.60 -2,258.630.85 549,291.126,012,397.043,742.92 0.00 3,061.53 7,000.00 89.06 3,803.26 3,063.57 -2,257.150.85 549,291.916,012,497.023,744.56 0.00 3,161.34 7,100.00 89.06 3,804.91 3,163.55 -2,255.670.85 549,292.706,012,596.993,746.21 0.00 3,261.15 7,200.00 89.06 3,806.56 3,263.52 -2,254.190.85 549,293.496,012,696.963,747.86 0.00 3,360.96 7,272.12 89.06 3,807.75 3,335.63 -2,253.120.85 549,294.056,012,769.073,749.05 0.00 3,432.94 Start Dir 3º/100' : 7272.12' MD, 3807.74'TVD 7,300.00 89.21 3,808.17 3,363.50 -2,252.511.67 549,294.476,012,796.943,749.47 3.00 3,460.75 7,345.10 89.46 3,808.69 3,408.55 -2,250.673.00 549,296.006,012,842.003,749.99 3.00 3,505.68 7,400.00 89.48 3,809.20 3,463.33 -2,247.014.65 549,299.286,012,896.793,750.50 3.00 3,560.24 7,465.36 89.50 3,809.78 3,528.37 -2,240.616.61 549,305.246,012,961.873,751.08 3.00 3,624.93 End Dir : 7465.36' MD, 3809.78' TVD 7,500.00 89.50 3,810.08 3,562.78 -2,236.626.61 549,308.996,012,996.303,751.38 0.00 3,659.13 7,600.00 89.50 3,810.95 3,662.11 -2,225.116.61 549,319.816,013,095.703,752.25 0.00 3,757.84 7,700.00 89.50 3,811.82 3,761.44 -2,213.616.61 549,330.626,013,195.103,753.12 0.00 3,856.56 7,800.00 89.50 3,812.69 3,860.77 -2,202.106.61 549,341.446,013,294.503,753.99 0.00 3,955.28 7,900.00 89.50 3,813.56 3,960.10 -2,190.596.61 549,352.266,013,393.903,754.86 0.00 4,054.00 8,000.00 89.50 3,814.43 4,059.44 -2,179.096.61 549,363.086,013,493.303,755.73 0.00 4,152.72 8,100.00 89.50 3,815.30 4,158.77 -2,167.586.61 549,373.906,013,592.703,756.60 0.00 4,251.44 8,200.00 89.50 3,816.17 4,258.10 -2,156.076.61 549,384.726,013,692.103,757.47 0.00 4,350.16 8,300.00 89.50 3,817.04 4,357.43 -2,144.576.61 549,395.536,013,791.503,758.34 0.00 4,448.88 8,325.98 89.50 3,817.26 4,383.24 -2,141.586.61 549,398.346,013,817.323,758.56 0.00 4,474.52 Start Dir 3º/100' : 8325.98' MD, 3817.26'TVD 8,400.00 88.81 3,818.35 4,456.59 -2,131.718.72 549,407.716,013,890.733,759.65 3.00 4,547.36 8,415.45 88.67 3,818.69 4,471.84 -2,129.319.16 549,410.006,013,906.003,759.99 3.00 4,562.49 8,415.69 88.67 3,818.70 4,472.08 -2,129.279.16 549,410.046,013,906.243,760.00 0.00 4,562.73 End Dir : 8415.69' MD, 3818.7' TVD 8,500.00 88.67 3,820.65 4,555.29 -2,115.869.15 549,422.876,013,989.533,761.95 0.01 4,645.26 8,600.00 88.67 3,822.98 4,653.99 -2,099.969.15 549,438.096,014,088.333,764.28 0.00 4,743.15 8,700.00 88.67 3,825.30 4,752.69 -2,084.069.15 549,453.306,014,187.133,766.60 0.00 4,841.04 8,800.00 88.67 3,827.63 4,851.40 -2,068.159.15 549,468.526,014,285.933,768.93 0.00 4,938.93 8,900.00 88.67 3,829.95 4,950.10 -2,052.259.15 549,483.746,014,384.733,771.25 0.00 5,036.82 9,000.00 88.67 3,832.27 5,048.80 -2,036.359.15 549,498.966,014,483.533,773.57 0.00 5,134.72 9,100.00 88.67 3,834.60 5,147.50 -2,020.459.15 549,514.186,014,582.323,775.90 0.00 5,232.61 9,200.00 88.67 3,836.92 5,246.20 -2,004.549.15 549,529.396,014,681.123,778.22 0.00 5,330.50 9,300.00 88.67 3,839.24 5,344.90 -1,988.649.15 549,544.616,014,779.923,780.54 0.00 5,428.39 9,400.00 88.67 3,841.57 5,443.60 -1,972.749.15 549,559.836,014,878.723,782.87 0.00 5,526.28 9,500.00 88.67 3,843.89 5,542.30 -1,956.849.15 549,575.056,014,977.523,785.19 0.00 5,624.17 9,600.00 88.67 3,846.22 5,641.00 -1,940.939.15 549,590.276,015,076.313,787.52 0.00 5,722.06 9,700.00 88.67 3,848.54 5,739.70 -1,925.039.15 549,605.496,015,175.113,789.84 0.00 5,819.95 9,800.00 88.67 3,850.86 5,838.40 -1,909.139.15 549,620.706,015,273.913,792.16 0.00 5,917.85 9,900.00 88.67 3,853.19 5,937.10 -1,893.239.15 549,635.926,015,372.713,794.49 0.00 6,015.74 10,000.00 88.67 3,855.51 6,035.80 -1,877.329.15 549,651.146,015,471.513,796.81 0.00 6,113.63 10,100.00 88.67 3,857.83 6,134.50 -1,861.429.15 549,666.366,015,570.303,799.13 0.00 6,211.52 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i 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 3,801.46 Vert Section 10,200.00 88.67 3,860.16 6,233.20 -1,845.529.15 549,681.586,015,669.103,801.46 0.00 6,309.41 10,300.00 88.67 3,862.48 6,331.90 -1,829.629.15 549,696.796,015,767.903,803.78 0.00 6,407.30 10,400.00 88.67 3,864.81 6,430.60 -1,813.719.15 549,712.016,015,866.703,806.11 0.00 6,505.19 10,500.00 88.67 3,867.13 6,529.30 -1,797.819.15 549,727.236,015,965.503,808.43 0.00 6,603.08 10,540.35 88.67 3,868.07 6,569.12 -1,791.399.15 549,733.376,016,005.363,809.37 0.00 6,642.58 Start Dir 3º/100' : 10540.35' MD, 3868.07'TVD 10,569.37 88.87 3,868.69 6,597.73 -1,786.5710.00 549,738.006,016,034.003,809.99 3.00 6,670.95 10,600.00 88.87 3,869.29 6,627.85 -1,781.0110.92 549,743.356,016,064.153,810.59 3.00 6,700.78 10,638.90 88.87 3,870.06 6,665.96 -1,773.2512.09 549,750.846,016,102.313,811.36 3.00 6,738.51 End Dir : 10638.9' MD, 3870.06' TVD 10,700.00 88.87 3,871.26 6,725.69 -1,760.4612.09 549,763.226,016,162.133,812.56 0.00 6,797.61 10,800.00 88.87 3,873.23 6,823.45 -1,739.5312.09 549,783.476,016,260.023,814.53 0.00 6,894.35 10,900.00 88.87 3,875.19 6,921.22 -1,718.5912.09 549,803.736,016,357.923,816.49 0.00 6,991.08 11,000.00 88.87 3,877.16 7,018.98 -1,697.6612.09 549,823.996,016,455.823,818.46 0.00 7,087.81 11,100.00 88.87 3,879.12 7,116.75 -1,676.7212.09 549,844.246,016,553.713,820.42 0.00 7,184.54 11,200.00 88.87 3,881.09 7,214.51 -1,655.7912.09 549,864.506,016,651.613,822.39 0.00 7,281.27 11,300.00 88.87 3,883.06 7,312.28 -1,634.8512.09 549,884.756,016,749.513,824.36 0.00 7,378.00 11,400.00 88.87 3,885.02 7,410.04 -1,613.9212.09 549,905.016,016,847.413,826.32 0.00 7,474.74 11,500.00 88.87 3,886.99 7,507.81 -1,592.9912.09 549,925.276,016,945.303,828.29 0.00 7,571.47 11,600.00 88.87 3,888.95 7,605.57 -1,572.0512.09 549,945.526,017,043.203,830.25 0.00 7,668.20 11,700.00 88.87 3,890.92 7,703.33 -1,551.1212.09 549,965.786,017,141.103,832.22 0.00 7,764.93 11,800.00 88.87 3,892.89 7,801.10 -1,530.1812.09 549,986.036,017,239.003,834.19 0.00 7,861.66 11,900.00 88.87 3,894.85 7,898.86 -1,509.2512.09 550,006.296,017,336.893,836.15 0.00 7,958.39 12,000.00 88.87 3,896.82 7,996.63 -1,488.3112.09 550,026.556,017,434.793,838.12 0.00 8,055.13 12,100.00 88.87 3,898.78 8,094.39 -1,467.3812.09 550,046.806,017,532.693,840.08 0.00 8,151.86 12,200.00 88.87 3,900.75 8,192.16 -1,446.4412.09 550,067.066,017,630.593,842.05 0.00 8,248.59 12,300.00 88.87 3,902.71 8,289.92 -1,425.5112.09 550,087.326,017,728.483,844.01 0.00 8,345.32 12,400.00 88.87 3,904.68 8,387.69 -1,404.5712.09 550,107.576,017,826.383,845.98 0.00 8,442.05 12,500.00 88.87 3,906.65 8,485.45 -1,383.6412.09 550,127.836,017,924.283,847.95 0.00 8,538.78 12,600.00 88.87 3,908.61 8,583.21 -1,362.7112.09 550,148.086,018,022.173,849.91 0.00 8,635.52 12,700.00 88.87 3,910.58 8,680.98 -1,341.7712.09 550,168.346,018,120.073,851.88 0.00 8,732.25 12,800.00 88.87 3,912.54 8,778.74 -1,320.8412.09 550,188.606,018,217.973,853.84 0.00 8,828.98 12,900.00 88.87 3,914.51 8,876.51 -1,299.9012.09 550,208.856,018,315.873,855.81 0.00 8,925.71 13,000.00 88.87 3,916.48 8,974.27 -1,278.9712.09 550,229.116,018,413.763,857.78 0.00 9,022.44 13,100.00 88.87 3,918.44 9,072.04 -1,258.0312.09 550,249.366,018,511.663,859.74 0.00 9,119.17 13,200.00 88.87 3,920.41 9,169.80 -1,237.1012.09 550,269.626,018,609.563,861.71 0.00 9,215.91 13,300.00 88.87 3,922.37 9,267.57 -1,216.1612.09 550,289.886,018,707.463,863.67 0.00 9,312.64 13,400.00 88.87 3,924.34 9,365.33 -1,195.2312.09 550,310.136,018,805.353,865.64 0.00 9,409.37 13,500.00 88.87 3,926.31 9,463.09 -1,174.2912.09 550,330.396,018,903.253,867.61 0.00 9,506.10 13,600.00 88.87 3,928.27 9,560.86 -1,153.3612.09 550,350.646,019,001.153,869.57 0.00 9,602.83 13,700.00 88.87 3,930.24 9,658.62 -1,132.4312.09 550,370.906,019,099.053,871.54 0.00 9,699.57 13,800.00 88.87 3,932.20 9,756.39 -1,111.4912.09 550,391.166,019,196.943,873.50 0.00 9,796.30 13,900.00 88.87 3,934.17 9,854.15 -1,090.5612.09 550,411.416,019,294.843,875.47 0.00 9,893.03 14,000.00 88.87 3,936.13 9,951.92 -1,069.6212.09 550,431.676,019,392.743,877.43 0.00 9,989.76 14,100.00 88.87 3,938.10 10,049.68 -1,048.6912.09 550,451.926,019,490.633,879.40 0.00 10,086.49 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i 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 3,879.99 Vert Section 14,130.00 88.87 3,938.69 10,079.01 -1,042.4112.09 550,458.006,019,520.003,879.99 0.00 10,115.51 Start Dir 3º/100' : 14130' MD, 3938.69'TVD 14,200.00 88.03 3,940.58 10,147.17 -1,026.6114.01 550,473.326,019,588.273,881.88 3.00 10,182.90 14,289.77 86.94 3,944.52 10,233.69 -1,003.0316.48 550,496.306,019,674.943,885.82 3.00 10,268.28 End Dir : 14289.77' MD, 3944.52' TVD 14,300.00 86.94 3,945.07 10,243.49 -1,000.1416.48 550,499.136,019,684.763,886.37 0.00 10,277.94 14,400.00 86.94 3,950.40 10,339.25 -971.8116.48 550,526.796,019,780.703,891.70 0.00 10,372.34 14,500.00 86.94 3,955.73 10,435.00 -943.4916.48 550,554.446,019,876.643,897.03 0.00 10,466.73 14,600.00 86.94 3,961.06 10,530.76 -915.1716.48 550,582.106,019,972.583,902.36 0.00 10,561.13 14,700.00 86.94 3,966.39 10,626.52 -886.8416.48 550,609.766,020,068.523,907.69 0.00 10,655.52 14,800.00 86.94 3,971.72 10,722.27 -858.5216.48 550,637.426,020,164.463,913.02 0.00 10,749.92 14,900.00 86.94 3,977.05 10,818.03 -830.2016.48 550,665.076,020,260.403,918.35 0.00 10,844.32 15,000.00 86.94 3,982.38 10,913.79 -801.8816.48 550,692.736,020,356.353,923.68 0.00 10,938.71 15,100.00 86.94 3,987.71 11,009.55 -773.5516.48 550,720.396,020,452.293,929.01 0.00 11,033.11 15,200.00 86.94 3,993.04 11,105.30 -745.2316.48 550,748.056,020,548.233,934.34 0.00 11,127.51 15,300.00 86.94 3,998.37 11,201.06 -716.9116.48 550,775.706,020,644.173,939.67 0.00 11,221.90 15,400.00 86.94 4,003.70 11,296.82 -688.5816.48 550,803.366,020,740.113,945.00 0.00 11,316.30 15,500.00 86.94 4,009.03 11,392.57 -660.2616.48 550,831.026,020,836.053,950.33 0.00 11,410.69 15,600.00 86.94 4,014.36 11,488.33 -631.9416.48 550,858.686,020,931.993,955.66 0.00 11,505.09 15,700.00 86.94 4,019.70 11,584.09 -603.6116.48 550,886.346,021,027.933,961.00 0.00 11,599.49 15,800.00 86.94 4,025.03 11,679.84 -575.2916.48 550,913.996,021,123.873,966.33 0.00 11,693.88 15,900.00 86.94 4,030.36 11,775.60 -546.9716.48 550,941.656,021,219.823,971.66 0.00 11,788.28 15,962.73 86.94 4,033.70 11,835.67 -529.2016.48 550,959.006,021,280.003,975.00 0.00 11,847.49 Total Depth : 15962.73' MD, 4033.7' TVD - 4 1/2" x 8 1/2" 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 8 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt I Pad Halliburton Standard Proposal Report Well: Wellbore: Plan: MPU I-37i MPU I-37i Survey Calculation Method:Minimum Curvature MPU I-37 As-Staked Location @ 58.70usft (Origi Design:MPU I-37 wp06 Database:NORTH US + CANADA MD Reference:MPU I-37 As-Staked Location @ 58.70usft (Origi North Reference: Well Plan: MPU I-37i True Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Tar gets Dip Angle (°) Dip Dir. (°) MPI-Richmond wp06 Heel 3,773.70 6,010,993.00 549,280.001,559.53 -2,279.460.00 0.00 -plan hits target center - Circle (radius 30.00) MPI-Richmond wp05 CP4 3,938.69 6,019,520.00 550,458.0010,079.01 -1,042.410.00 0.00 -plan hits target center - Point MPI-Richmond wp05 Toe 4,033.70 6,021,280.00 550,959.0011,835.67 -529.200.00 0.00 -plan hits target center - Point MPI-Richmond wp02 CP1 3,808.69 6,012,842.00 549,296.003,408.55 -2,250.670.00 0.00 -plan hits target center - Point MPI-Richmond wp02 CP2 3,818.69 6,013,906.00 549,410.004,471.84 -2,129.310.00 0.00 -plan hits target center - Point MPI-Richmond wp02 CP3 3,868.69 6,016,034.00 549,738.006,597.73 -1,786.570.00 0.00 -plan hits target center - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 9 5/8" x 12 1/4"3,773.705,495.39 9-5/8 12-1/4 4 1/2" x 8 1/2"4,033.7015,962.73 4-1/2 8-1/2 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 320.00 320.00 0.00 0.00 Start Dir 3º/100' : 320' MD, 320'TVD 579.33 578.83 11.95 -7.61 End Dir : 579.33' MD, 578.82' TVD 850.00 848.47 23.74 -28.04 Start Dir 3º/100' : 850' MD, 848.46'TVD 1,084.41 1,080.16 39.17 -59.01 End Dir : 1084.41' MD, 1080.16' TVD 1,200.00 1,193.23 49.32 -80.79 Start Dir 3º/100' : 1200' MD, 1193.23'TVD 1,368.08 1,357.42 57.37 -115.54 Start Dir 4º/100' : 1368.08' MD, 1357.43'TVD 2,356.67 2,175.60 50.68 -636.93 End Dir : 2356.67' MD, 2175.6' TVD 3,286.34 2,791.70 99.25 -1,331.45 Start Dir 4º/100' : 3286.34' MD, 2791.7'TVD 5,395.39 3,764.98 1,459.92 -2,281.01 End Dir : 5395.39' MD, 3764.98' TVD 5,495.39 3,773.70 1,559.52 -2,279.46 Start Dir 3º/100' : 5495.39' MD, 3773.7'TVD 5,630.61 3,780.71 1,694.52 -2,277.42 End Dir : 5630.61' MD, 3780.71' TVD 7,272.12 3,807.75 3,335.63 -2,253.12 Start Dir 3º/100' : 7272.12' MD, 3807.74'TVD 7,465.36 3,809.78 3,528.37 -2,240.61 End Dir : 7465.36' MD, 3809.78' TVD 8,325.98 3,817.26 4,383.24 -2,141.58 Start Dir 3º/100' : 8325.98' MD, 3817.26'TVD 8,415.69 3,818.70 4,472.08 -2,129.27 End Dir : 8415.69' MD, 3818.7' TVD 10,540.35 3,868.07 6,569.12 -1,791.39 Start Dir 3º/100' : 10540.35' MD, 3868.07'TVD 10,638.90 3,870.06 6,665.96 -1,773.25 End Dir : 10638.9' MD, 3870.06' TVD 14,130.00 3,938.69 10,079.01 -1,042.41 Start Dir 3º/100' : 14130' MD, 3938.69'TVD 14,289.77 3,944.52 10,233.69 -1,003.03 End Dir : 14289.77' MD, 3944.52' TVD 15,962.73 4,033.70 11,835.67 -529.20 Total Depth : 15962.73' MD, 4033.7' TVD 6/16/2020 12:43:15PM COMPASS 5000.15 Build 91E Page 9 16 June, 2020Milne PointM Pt I PadPlan: MPU I-37iMPU I-37iMPU I-37 wp06Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,009,449.42 N, 551,569.97 E (70° 26' 11.63" N, 149° 34' 46.35" W)Datum Height: MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Scan Range: 26.50 to 5,495.39 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 usftGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referenceScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 26.50 to 5,495.39 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningEX WSAK-25WSAK-25 - WSAK-25 - WSAK-25180.20 5,434.57 109.84 3,922.79 2.5615,434.57Ellipse Separation Pass - WSAK-25 - WSAK-25 - WSAK-25180.87 5,451.50 109.87 3,915.98 2.5485,451.50Clearance Factor Pass - M Pt I PadMPI-01 - MPI-01 - MPI-01105.28 26.50 103.71 37.79 66.89126.50Centre Distance Pass - MPI-01 - MPI-01 - MPI-01105.73 176.50 103.55 187.10 48.623176.50Ellipse Separation Pass - MPI-01 - MPI-01 - MPI-01132.61 626.50 127.07 624.54 23.916626.50Clearance Factor Pass - MPI-02 - MPI-02 - MPI-0245.12 326.50 41.86 337.82 13.833326.50Centre Distance Pass - MPI-02 - MPI-02 - MPI-0245.22 351.50 41.77 362.78 13.113351.50Ellipse Separation Pass - MPI-02 - MPI-02 - MPI-0252.39 526.50 47.60 535.81 10.939526.50Clearance Factor Pass - MPI-03 - MPI-03 - MPI-0311.37 437.88 7.26 449.19 2.767437.88Centre Distance Pass - MPI-03 - MPI-03 - MPI-0311.44 451.50 7.23 462.76 2.714451.50Clearance Factor Pass - MPI-04 - MPI-04 - MPI-0439.53 840.72 32.27 850.99 5.446840.72Ellipse Separation Pass - MPI-04 - MPI-04 - MPI-0439.62 851.50 32.30 861.41 5.411851.50Clearance Factor Pass - MPI-04 - MPI-04A - MPI-04A39.53 840.72 32.27 850.99 5.446840.72Ellipse Separation Pass - MPI-04 - MPI-04A - MPI-04A39.62 851.50 32.30 861.41 5.411851.50Clearance Factor Pass - MPI-04 - MPI-04AL1 - MPI-04AL139.53 840.72 32.27 850.99 5.446840.72Ellipse Separation Pass - MPI-04 - MPI-04AL1 - MPI-04AL139.62 851.50 32.30 861.41 5.411851.50Clearance Factor Pass - MPI-04 - MPI-04APB1 - MPI-04APB139.53 840.72 32.27 850.99 5.446840.72Ellipse Separation Pass - MPI-04 - MPI-04APB1 - MPI-04APB139.62 851.50 32.30 861.41 5.411851.50Clearance Factor Pass - MPI-04 - MPI-04PB1 - MPI-04PB139.53 840.72 32.27 850.99 5.446840.72Ellipse Separation Pass - MPI-04 - MPI-04PB1 - MPI-04PB139.62 851.50 32.30 861.41 5.411851.50Clearance Factor Pass - MPI-05 - MPI-05 - MPI-0515.07 327.38 12.33 332.71 5.509327.38Centre Distance Pass - MPI-05 - MPI-05 - MPI-0515.13 351.50 12.25 356.83 5.262351.50Ellipse Separation Pass - MPI-05 - MPI-05 - MPI-0516.30 426.50 12.98 431.77 4.914426.50Clearance Factor Pass - MPI-06 - MPI-06 - MPI-0639.08 691.67 33.01 694.86 6.437691.67Centre Distance Pass - MPI-06 - MPI-06 - MPI-0639.10 701.50 32.95 704.53 6.359701.50Ellipse Separation Pass - MPI-06 - MPI-06 - MPI-0641.29 776.50 34.55 777.94 6.128776.50Clearance Factor Pass - 16 June, 2020-12:44COMPASSPage 2 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 26.50 to 5,495.39 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-07 - MPI-07 - MPI-0749.85 1,183.52 42.24 1,182.53 6.5501,183.52Ellipse Separation Pass - MPI-07 - MPI-07 - MPI-0751.89 1,276.50 43.71 1,273.50 6.3461,276.50Clearance Factor Pass - MPI-08 - MPI-08 - MPI-0895.68 1,662.03 85.41 1,627.27 9.3231,662.03Centre Distance Pass - MPI-08 - MPI-08 - MPI-0895.87 1,701.50 85.18 1,665.45 8.9681,701.50Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-08565.56 5,176.50 473.25 4,978.75 6.1275,176.50Clearance Factor Pass - MPI-09 - MPI-09 - MPI-0974.37 170.94 71.95 174.49 30.721170.94Centre Distance Pass - MPI-09 - MPI-09 - MPI-0974.99 276.50 71.46 279.18 21.232276.50Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-09984.72 5,495.39 818.01 4,913.62 5.9065,495.39Clearance Factor Pass - MPI-10 - MPI-10 - MPI-10106.35 2,342.11 63.33 2,474.43 2.4722,342.11Centre Distance Pass - MPI-10 - MPI-10 - MPI-10106.45 2,351.50 63.01 2,482.57 2.4512,351.50Ellipse Separation Pass - MPI-10 - MPI-10 - MPI-10107.53 2,376.50 63.12 2,504.28 2.4212,376.50Clearance Factor Pass - MPI-11 - MPI-11 - MPI-11164.01 288.88 161.59 293.75 67.967288.88Centre Distance Pass - MPI-11 - MPI-11 - MPI-11164.21 451.50 160.84 451.79 48.818451.50Ellipse Separation Pass - MPI-11 - MPI-11 - MPI-11375.44 2,801.50 341.21 2,535.19 10.9702,801.50Clearance Factor Pass - MPI-11 - MPI-11L1 - MPI-11L1164.01 288.88 161.59 293.75 67.967288.88Centre Distance Pass - MPI-11 - MPI-11L1 - MPI-11L1164.21 451.50 160.84 451.79 48.818451.50Ellipse Separation Pass - MPI-11 - MPI-11L1 - MPI-11L1375.44 2,801.50 341.21 2,535.19 10.9702,801.50Clearance Factor Pass - MPI-12 - MPI-12 - MPI-12110.95 2,136.01 91.81 2,054.24 5.7962,136.01Centre Distance Pass - MPI-12 - MPI-12 - MPI-12112.26 2,201.50 90.43 2,113.49 5.1422,201.50Ellipse Separation Pass - MPI-12 - MPI-12 - MPI-12135.30 2,526.50 99.97 2,418.44 3.8292,526.50Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L1110.95 2,136.01 91.81 2,054.24 5.7962,136.01Centre Distance Pass - MPI-12 - MPI-12L1 - MPI-12L1112.26 2,201.50 90.43 2,113.49 5.1422,201.50Ellipse Separation Pass - MPI-12 - MPI-12L1 - MPI-12L1135.30 2,526.50 99.97 2,418.44 3.8292,526.50Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB1110.95 2,136.01 91.80 2,054.24 5.7942,136.01Centre Distance Pass - MPI-12 - MPI-12PB1 - MPI-12PB1112.26 2,201.50 90.42 2,113.49 5.1402,201.50Ellipse Separation Pass - MPI-12 - MPI-12PB1 - MPI-12PB1135.30 2,526.50 99.95 2,418.44 3.8272,526.50Clearance Factor Pass - MPI-13 - MPI-13 - MPI-13223.35 617.90 219.22 605.95 54.080617.90Centre Distance Pass - MPI-13 - MPI-13 - MPI-13223.46 651.50 219.13 638.23 51.624651.50Ellipse Separation Pass - MPI-13 - MPI-13 - MPI-13269.94 2,576.50 253.54 2,315.41 16.4552,576.50Clearance Factor Pass - MPI-14 - MPI-14 - MPI-14253.90 713.50 248.37 703.28 45.935713.50Centre Distance Pass - 16 June, 2020-12:44COMPASSPage 3 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 26.50 to 5,495.39 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-14 - MPI-14 - MPI-14254.06 776.50 248.23 765.08 43.611776.50Ellipse Separation Pass - MPI-14 - MPI-14 - MPI-141,245.16 4,876.50 1,140.26 4,021.98 11.8704,876.50Clearance Factor Pass - MPI-14 - MPI-14L1 - MPI-14L1253.90 713.50 248.37 703.28 45.935713.50Centre Distance Pass - MPI-14 - MPI-14L1 - MPI-14L1254.06 776.50 248.23 765.08 43.611776.50Ellipse Separation Pass - MPI-14 - MPI-14L1 - MPI-14L11,245.16 4,876.50 1,140.39 4,021.98 11.8854,876.50Clearance Factor Pass - MPI-14 - MPI-14L2 - MPI-14L2253.90 713.50 248.37 703.28 45.935713.50Centre Distance Pass - MPI-14 - MPI-14L2 - MPI-14L2254.06 776.50 248.23 765.08 43.611776.50Ellipse Separation Pass - MPI-14 - MPI-14L2 - MPI-14L21,245.16 4,876.50 1,140.42 4,021.98 11.8874,876.50Clearance Factor Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1253.90 713.50 248.37 703.28 45.935713.50Centre Distance Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1254.06 776.50 248.23 765.08 43.611776.50Ellipse Separation Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB11,245.16 4,876.50 1,140.13 4,021.98 11.8554,876.50Clearance Factor Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2253.90 713.50 248.37 703.28 45.935713.50Centre Distance Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2254.06 776.50 248.23 765.08 43.611776.50Ellipse Separation Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB21,245.16 4,876.50 1,140.13 4,021.98 11.8554,876.50Clearance Factor Pass - MPI-14 - MPI-14PB1 - MPI-14PB1253.90 713.50 248.37 703.28 45.935713.50Centre Distance Pass - MPI-14 - MPI-14PB1 - MPI-14PB1254.06 776.50 248.23 765.08 43.611776.50Ellipse Separation Pass - MPI-14 - MPI-14PB1 - MPI-14PB11,245.16 4,876.50 1,140.26 4,021.98 11.8704,876.50Clearance Factor Pass - MPI-14 - MPI-14PB2 - MPI-14PB2253.90 713.50 248.37 703.28 45.935713.50Centre Distance Pass - MPI-14 - MPI-14PB2 - MPI-14PB2254.06 776.50 248.23 765.08 43.611776.50Ellipse Separation Pass - MPI-14 - MPI-14PB2 - MPI-14PB21,245.16 4,876.50 1,140.26 4,021.98 11.8704,876.50Clearance Factor Pass - MPI-15 - MPI-15 - MPI-15159.82 26.50 157.97 30.30 86.10426.50Centre Distance Pass - MPI-15 - MPI-15 - MPI-15160.05 301.50 157.08 304.84 53.796301.50Ellipse Separation Pass - MPI-15 - MPI-15 - MPI-15210.31 801.50 204.92 782.20 39.042801.50Clearance Factor Pass - MPI-15 - MPI-15L1 - MPI-15L1159.82 26.50 157.97 30.30 86.10426.50Centre Distance Pass - MPI-15 - MPI-15L1 - MPI-15L1160.05 301.50 157.08 304.84 53.796301.50Ellipse Separation Pass - MPI-15 - MPI-15L1 - MPI-15L1210.31 801.50 204.92 782.20 39.042801.50Clearance Factor Pass - MPI-15 - MPI-15PB1 - MPI-15PB1159.82 26.50 157.97 30.30 86.10426.50Centre Distance Pass - MPI-15 - MPI-15PB1 - MPI-15PB1160.05 301.50 157.08 304.84 53.796301.50Ellipse Separation Pass - MPI-15 - MPI-15PB1 - MPI-15PB1210.31 801.50 204.92 782.20 39.042801.50Clearance Factor Pass - MPI-16 - MPI-16 - MPI-16189.03 326.50 185.59 336.66 54.862326.50Centre Distance Pass - 16 June, 2020-12:44COMPASSPage 4 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 26.50 to 5,495.39 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-16 - MPI-16 - MPI-16189.16 351.50 185.53 361.11 52.049351.50Ellipse Separation Pass - MPI-16 - MPI-16 - MPI-161,016.60 3,301.50 956.12 3,179.99 16.8113,301.50Clearance Factor Pass - MPI-17 - MPI-17 - MPI-17219.86 26.50 218.00 36.11 118.56726.50Centre Distance Pass - MPI-17 - MPI-17 - MPI-17221.24 526.50 215.40 546.51 37.924526.50Ellipse Separation Pass - MPI-17 - MPI-17 - MPI-17662.71 4,726.50 502.88 5,700.06 4.1464,726.50Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L1219.86 26.50 218.00 36.11 118.56726.50Centre Distance Pass - MPI-17 - MPI-17L1 - MPI-17L1221.24 526.50 215.40 546.51 37.924526.50Ellipse Separation Pass - MPI-17 - MPI-17L1 - MPI-17L1653.30 4,776.50 517.68 5,693.87 4.8174,776.50Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1219.86 26.50 218.00 36.11 118.56726.50Centre Distance Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1221.24 526.50 215.40 546.51 37.924526.50Ellipse Separation Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1653.30 4,776.50 517.55 5,693.87 4.8134,776.50Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L2219.86 26.50 218.00 36.11 118.56726.50Centre Distance Pass - MPI-17 - MPI-17L2 - MPI-17L2221.24 526.50 215.40 546.51 37.924526.50Ellipse Separation Pass - MPI-17 - MPI-17L2 - MPI-17L2692.79 4,626.50 566.58 5,469.24 5.4894,626.50Clearance Factor Pass - MPI-19 - MPI-19 - MPI-19280.09 26.50 278.24 36.69 151.37526.50Ellipse Separation Pass - MPI-19 - MPI-19 - MPI-19372.04 1,426.50 360.49 1,443.63 32.2051,426.50Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1280.09 26.50 278.24 36.69 151.37526.50Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1372.04 1,426.50 360.49 1,443.63 32.2051,426.50Clearance Factor Pass - MPU I-35i - MPU I-35i - MPU I-35i233.96 26.50 232.05 28.13 122.39826.50Ellipse Separation Pass - MPU I-35i - MPU I-35i - MPU I-35i370.25 1,726.50 359.45 1,785.04 34.2761,726.50Clearance Factor Pass - MPU I-36 - MPU I-36 - MPU I-36117.54 460.24 114.21 465.10 35.287460.24Centre Distance Pass - MPU I-36 - MPU I-36 - MPU I-36117.56 476.50 114.15 481.34 34.472476.50Ellipse Separation Pass - MPU I-36 - MPU I-36 - MPU I-36476.31 2,726.50 451.23 2,802.96 18.9892,726.50Clearance Factor Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1117.54 460.24 114.21 465.10 35.287460.24Centre Distance Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1117.56 476.50 114.15 481.34 34.472476.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1476.31 2,726.50 451.23 2,802.96 18.9892,726.50Clearance Factor Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2117.54 460.24 114.21 465.10 35.287460.24Centre Distance Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2117.56 476.50 114.15 481.34 34.472476.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2476.31 2,726.50 451.25 2,802.96 19.0062,726.50Clearance Factor Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21 wp08202.06 476.50 198.55 484.68 57.569476.50Ellipse Separation Pass - 16 June, 2020-12:44COMPASSPage 5 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 26.50 to 5,495.39 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-21i - MPU I-21 - MPU I-21 wp08353.77 1,976.50 340.93 2,042.70 27.5571,976.50Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0390.05 301.50 87.38 303.80 33.733301.50Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp0390.34 426.50 87.09 430.55 27.801426.50Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03657.24 5,495.39 604.15 5,818.50 12.3805,495.39Clearance Factor Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp04264.02 301.50 261.35 302.90 98.955301.50Centre Distance Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp04264.12 351.50 261.23 352.90 91.409351.50Ellipse Separation Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp04390.79 1,501.50 382.58 1,541.33 47.5731,501.50Clearance Factor Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03173.07 493.46 169.47 501.50 48.048493.46Centre Distance Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03173.10 501.50 169.46 509.07 47.543501.50Ellipse Separation Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03209.53 1,876.50 198.89 1,961.11 19.6921,876.50Clearance Factor Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03146.65 407.36 143.48 411.69 46.258407.36Centre Distance Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03146.69 426.50 143.42 431.00 44.877426.50Ellipse Separation Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03366.83 3,601.50 318.15 3,801.00 7.5363,601.50Clearance Factor Pass - Rig: MPU I-20 - MPU I-20 - MPU I-20 wp06294.19 301.50 291.52 303.00 110.271301.50Centre Distance Pass - Rig: MPU I-20 - MPU I-20 - MPU I-20 wp06294.29 351.50 291.40 353.00 101.858351.50Ellipse Separation Pass - Rig: MPU I-20 - MPU I-20 - MPU I-20 wp06459.41 1,526.50 451.65 1,510.57 59.2411,526.50Clearance Factor Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 800.00 MPU I-37 wp06 3_Gyro-GC_Csg800.00 5,495.39 MPU I-37 wp06 3_MWD+IFR2+MS+Sag5,495.39 15,962.73 MPU I-37 wp06 3_MWD+IFR2+MS+Sag16 June, 2020-12:44COMPASSPage 6 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 wp06Ellipse 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.16 June, 2020-12:44COMPASSPage 7 of 9 0.001.002.003.004.00Separation Factor0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700Measured Depth (600 usft/in)MPI-03MPI-10MPI-08WSAK-25MPI-12L1MPI-12PB1MPI-17No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-37i NAD 1927 (NADCON CONUS)Alaska Zone 0432.20+N/-S +E/-W Northing Easting Latittude Longitude0.000.006009449.42 551569.9770° 26' 11.632 N149° 34' 46.348 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-37i, True NorthVertical (TVD) Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Measured Depth Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-06-16T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 800.00 MPU I-37 wp06 (MPU I-37i) 3_Gyro-GC_Csg800.00 5495.39 MPU I-37 wp06 (MPU I-37i) 3_MWD+IFR2+MS+Sag5495.39 15962.73 MPU I-37 wp06 (MPU I-37i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700Measured Depth (600 usft/in)MPI-03MPU I-22 wp03MPU I-29 wp03MPI-09MPI-10MPI-10MPU I-28i wp03MPI-05MPI-01MPI-06MPI-02MPI-15MPI-08MPI-04MPI-07MPU I-36MPI-11MPI-12NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 15962.73Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-37iWellbore: MPU I-37iPlan: MPU I-37 wp06Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3773.70 3715.00 5495.39 9-5/8 9 5/8" x 12 1/4"4033.70 3975.00 15962.73 4-1/2 4 1/2" x 8 1/2" 16 June, 2020Milne PointM Pt I PadPlan: MPU I-37iMPU I-37iMPU I-37 wp06Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,009,449.42 N, 551,569.97 E (70° 26' 11.63" N, 149° 34' 46.35" W)Datum Height: MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Scan Range: 5,495.39 to 15,962.73 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 usftGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referenceScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 5,495.39 to 15,962.73 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningEX WSAK-25WSAK-25 - WSAK-25 - WSAK-25188.60 5,495.39 116.62 3,898.05 2.6205,495.39Clearance Factor Pass - M Pt I PadMPI-08 - MPI-08 - MPI-08337.99 5,687.69 235.69 5,253.02 3.3045,687.69Centre Distance Pass - MPI-08 - MPI-08 - MPI-08360.54 5,820.39 208.75 5,297.05 2.3755,820.39Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-08390.95 5,895.39 220.17 5,321.68 2.2895,895.39Clearance Factor Pass - MPI-09 - MPI-09 - MPI-0954.096,820.39-165.305,873.980.2476,820.39Ellipse SeparationFAIL - MPI-09 - MPI-09 - MPI-0941.486,845.39-155.775,891.050.2106,845.39Clearance FactorFAIL - MPI-09 - MPI-09 - MPI-0933.846,878.35-71.385,913.590.3226,878.35Centre DistanceFAIL - MPI-12 - MPI-12 - MPI-121,556.77 5,495.39 1,442.61 4,260.24 13.6375,495.39Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L11,556.77 5,495.39 1,442.61 4,260.24 13.6375,495.39Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB11,556.77 5,495.39 1,442.33 4,260.24 13.6045,495.39Clearance Factor Pass - MPI-14 - MPI-14 - MPI-141,746.78 5,495.39 1,614.50 4,120.46 13.2055,495.39Clearance Factor Pass - MPI-14 - MPI-14L1 - MPI-14L11,746.78 5,495.39 1,614.63 4,120.46 13.2185,495.39Clearance Factor Pass - MPI-14 - MPI-14L2 - MPI-14L21,746.78 5,495.39 1,614.65 4,120.46 13.2205,495.39Clearance Factor Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB11,746.78 5,495.39 1,614.37 4,120.46 13.1925,495.39Clearance Factor Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB21,746.78 5,495.39 1,614.37 4,120.46 13.1925,495.39Clearance Factor Pass - MPI-14 - MPI-14PB1 - MPI-14PB11,746.78 5,495.39 1,614.50 4,120.46 13.2055,495.39Clearance Factor Pass - MPI-14 - MPI-14PB2 - MPI-14PB21,746.78 5,495.39 1,614.50 4,120.46 13.2055,495.39Clearance Factor Pass - MPI-17 - MPI-17 - MPI-171,297.24 5,495.39 1,109.58 5,882.29 6.9135,495.39Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L11,232.53 5,495.39 1,071.75 5,842.72 7.6665,495.39Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB11,232.53 5,495.39 1,071.62 5,842.72 7.6605,495.39Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L21,398.20 5,495.39 1,239.55 5,833.27 8.8135,495.39Clearance Factor Pass - MPI-19 - MPI-19 - MPI-191,123.85 11,620.39 921.10 9,720.00 5.54311,620.39Clearance Factor Pass - MPI-19 - MPI-19 - MPI-191,120.08 11,695.39 919.08 9,720.00 5.57311,695.39Ellipse Separation Pass - MPI-19 - MPI-19 - MPI-191,119.92 11,714.34 919.49 9,720.00 5.58811,714.34Centre Distance Pass - MPI-19 - MPI-19L1 - MPI-19L1161.61 11,991.67 89.76 10,764.50 2.24911,991.67Centre Distance Pass - MPI-19 - MPI-19L1 - MPI-19L1170.31 12,045.39 83.17 10,763.86 1.95512,045.39Ellipse Separation Pass - 16 June, 2020-12:45COMPASSPage 2 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 5,495.39 to 15,962.73 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-19 - MPI-19L1 - MPI-19L1192.03 12,095.39 89.79 10,763.30 1.87812,095.39Clearance Factor Pass - MPU I-35i - MPU I-35i - MPU I-35i1,733.08 14,120.39 1,468.16 13,130.00 6.54214,120.39Clearance Factor Pass - MPU I-35i - MPU I-35i - MPU I-35i1,730.35 14,245.39 1,466.64 13,130.00 6.56214,245.39Ellipse Separation Pass - MPU I-35i - MPU I-35i - MPU I-35i1,729.61 14,310.27 1,467.02 13,130.00 6.58714,310.27Centre Distance Pass - MPU I-36 - MPU I-36 - MPU I-36790.07 14,595.39 538.56 14,265.00 3.14114,595.39Clearance Factor Pass - MPU I-36 - MPU I-36 - MPU I-36786.39 14,645.39 536.68 14,265.00 3.14914,645.39Ellipse Separation Pass - MPU I-36 - MPU I-36 - MPU I-36785.70 14,678.45 537.68 14,265.00 3.16814,678.45Centre Distance Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB11,076.36 10,620.39 899.16 10,300.00 6.07410,620.39Clearance Factor Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB11,075.61 10,645.39 898.90 10,300.00 6.08710,645.39Ellipse Separation Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB11,075.36 10,668.86 899.16 10,300.00 6.10310,668.86Centre Distance Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB21,092.70 5,495.39 1,039.51 5,312.06 20.5465,495.39Centre Distance Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB21,104.75 10,420.39 936.41 10,163.00 6.56210,420.39Clearance Factor Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB21,103.30 10,470.39 935.68 10,163.00 6.58210,470.39Ellipse Separation Pass - Plan: MPU I-21i - MPU I-21 - MPU I-21 wp08889.26 15,962.73 594.09 15,574.70 3.01315,962.73Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03419.37 14,345.39 192.47 14,570.85 1.84814,345.39Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03417.14 14,388.52 194.66 14,570.85 1.87514,388.52Centre Distance Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp041,598.98 15,645.39 1,313.89 14,858.11 5.60915,645.39Clearance Factor Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp041,596.26 15,720.39 1,312.44 14,858.11 5.62415,720.39Ellipse Separation Pass - Plan: MPU I-27 - MPU I-27 - MPU I-27 wp041,596.13 15,740.66 1,312.75 14,858.11 5.63215,740.66Centre Distance Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03926.75 15,820.39 636.39 15,276.27 3.19215,820.39Clearance Factor Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03923.43 15,870.39 634.55 15,276.27 3.19715,870.39Ellipse Separation Pass - Plan: MPU I-28i - MPU I-28 - MPU I-28i wp03922.71 15,906.84 635.40 15,276.27 3.21215,906.84Centre Distance Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03264.0115,895.39-4.5016,125.490.98315,895.39Clearance FactorFAIL - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03263.1515,916.68-1.7316,125.490.99315,916.68Centre DistanceFAIL - Rig: MPU I-20 - MPU I-20 - MPU I-20 wp061,591.50 15,962.73 1,294.52 15,199.64 5.35915,962.73Clearance Factor Pass - M Pt J PadMPJ-01 - MPJ-01A - MPJ-01A1,388.81 12,400.83 1,217.70 5,720.93 8.11712,400.83Ellipse Separation Pass - MPJ-01 - MPJ-01A - MPJ-01A1,643.73 14,720.39 1,372.52 8,034.00 6.06114,720.39Clearance Factor Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL11,534.21 14,420.39 1,292.02 7,952.00 6.33514,420.39Clearance Factor Pass - MPJ-01 - MPJ-01AL1 - MPJ-01AL11,527.06 14,545.39 1,287.25 7,952.00 6.36814,545.39Ellipse Separation Pass - 16 June, 2020-12:45COMPASSPage 3 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 5,495.39 to 15,962.73 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-01 - MPJ-01AL1 - MPJ-01AL11,526.86 14,570.34 1,287.69 7,952.00 6.38414,570.34Centre Distance Pass - MPJ-08 - MPJ-08 - MPJ-08101.2514,893.72-36.138,528.300.73714,893.72Centre DistanceFAIL - MPJ-08 - MPJ-08 - MPJ-08111.4514,995.39-120.208,593.000.48114,995.39Clearance FactorFAIL - MPJ-08 - MPJ-08A - MPJ-08A218.74 11,763.72 170.52 5,963.17 4.53611,763.72Centre Distance Pass - MPJ-08 - MPJ-08A - MPJ-08A250.95 11,895.39 143.75 6,011.95 2.34111,895.39Ellipse Separation Pass - MPJ-08 - MPJ-08A - MPJ-08A291.90 11,970.39 158.83 6,035.37 2.19411,970.39Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-0965.9211,387.66-66.285,370.300.49911,387.66Centre DistanceFAIL - MPJ-09 - MPJ-09 - MPJ-0979.5311,445.39-129.785,407.310.38011,445.39Clearance FactorFAIL - MPJ-09 - MPJ-09 - MPJ-0991.6811,470.39-129.845,423.530.41411,470.39Ellipse SeparationFAIL - MPJ-09 - MPJ-09A - MPJ-09A66.7911,384.59-58.095,365.120.53511,384.59Centre DistanceFAIL - MPJ-09 - MPJ-09A - MPJ-09A72.5011,420.39-108.595,387.510.40011,420.39Clearance FactorFAIL - MPJ-09 - MPJ-09A - MPJ-09A82.1811,445.39-122.475,400.240.40211,445.39Ellipse SeparationFAIL - MPJ-15 - MPJ-15 - MPJ-1597.7213,511.97-105.776,333.790.48013,511.97Centre DistanceFAIL - MPJ-15 - MPJ-15 - MPJ-15104.7513,570.39-167.346,379.210.38513,570.39Clearance FactorFAIL - MPJ-15 - MPJ-15 - MPJ-15120.3013,620.39-180.606,416.160.40013,620.39Ellipse SeparationFAIL - MPJ-16 - MPJ-16 - MPJ-16995.09 13,570.39 756.07 6,466.63 4.16313,570.39Clearance Factor Pass - MPJ-16 - MPJ-16 - MPJ-16989.05 13,695.39 752.80 6,558.72 4.18713,695.39Ellipse Separation Pass - MPJ-16 - MPJ-16 - MPJ-16988.04 13,776.24 754.00 6,625.30 4.22213,776.24Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17855.36 9,740.39 796.75 4,580.29 14.5959,740.39Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17861.76 9,845.39 795.05 4,586.83 12.9199,845.39Ellipse Separation Pass - MPJ-17 - MPJ-17 - MPJ-171,123.74 10,470.39 981.52 4,621.75 7.90210,470.39Clearance Factor Pass - MPJ-18 - MPJ-18 - MPJ-18658.05 11,821.48 567.34 5,379.21 7.25511,821.48Centre Distance Pass - MPJ-18 - MPJ-18 - MPJ-18683.65 12,045.39 539.92 5,498.61 4.75712,045.39Ellipse Separation Pass - MPJ-18 - MPJ-18 - MPJ-18856.55 12,495.39 628.13 5,775.41 3.75012,495.39Clearance Factor Pass - MPJ-19 - MPJ-19 - MPJ-19556.83 10,422.93 495.57 4,879.47 9.09010,422.93Centre Distance Pass - MPJ-19 - MPJ-19 - MPJ-19560.71 10,495.39 491.50 4,910.64 8.10110,495.39Ellipse Separation Pass - MPJ-19 - MPJ-19 - MPJ-19683.37 10,845.39 574.835,045.56 6.29610,845.39Clearance Factor Pass - MPJ-19 - MPJ-19A - MPJ-19A228.60 10,402.29 141.46 5,036.24 2.62310,402.29Centre Distance Pass - MPJ-19 - MPJ-19A - MPJ-19A237.52 10,470.39 130.91 5,058.11 2.22810,470.39Ellipse Separation Pass - MPJ-19 - MPJ-19A - MPJ-19A254.48 10,520.39 136.64 5,074.43 2.16010,520.39Clearance Factor Pass - 16 June, 2020-12:45COMPASSPage 4 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 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: 5,495.39 to 15,962.73 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-37i - MPU I-37i - MPU I-37 wp06MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-21 - MPJ-21 - MPJ-21778.52 7,920.39 643.71 5,374.83 5.7757,920.39Clearance Factor Pass - MPJ-21 - MPJ-21 - MPJ-21665.77 8,245.39 568.49 5,285.70 6.8448,245.39Ellipse Separation Pass - MPJ-21 - MPJ-21 - MPJ-21658.63 8,345.39 574.48 5,258.92 7.8268,345.39Centre Distance Pass - MPJ-22 - MPJ-22 - MPJ-2217.989,486.56-45.244,994.650.2849,486.56Centre DistanceFAIL - MPJ-22 - MPJ-22 - MPJ-2219.999,495.39-86.224,996.040.1889,495.39Clearance FactorFAIL - MPJ-22 - MPJ-22 - MPJ-2237.949,520.39-122.804,999.960.2369,520.39Ellipse SeparationFAIL - MPJ-25 - MPJ-25 - MPJ-2525.4510,970.39-121.735,433.420.17310,970.39Ellipse SeparationFAIL - MPJ-25 - MPJ-25 - MPJ-256.6710,995.19-35.745,436.820.15710,995.19Centre DistanceFAIL - MPJ-25 - MPJ-25 - MPJ-256.6710,995.39-36.205,436.850.15610,995.39Clearance FactorFAIL - MPJ-25 - MPJ-25PB1 - MPJ-25PB1893.04 10,520.39 755.98 4,800.00 6.51610,520.39Clearance Factor Pass - MPJ-25 - MPJ-25PB1 - MPJ-25PB1833.73 10,795.39 714.59 4,800.00 6.99810,795.39Ellipse Separation Pass - MPJ-25 - MPJ-25PB1 - MPJ-25PB1831.68 10,853.87 717.13 4,800.00 7.26010,853.87Centre Distance Pass - MPJ-26 - MPJ-26 - MPJ-2685.278,795.39-24.724,803.860.7758,795.39Clearance FactorFAIL - MPJ-26 - MPJ-26 - MPJ-2669.598,845.419.594,795.391.1608,845.41Centre DistancePass - MPJ-26 - MPJ-26L1 - MPJ-26L185.278,795.39-24.724,803.860.7758,795.39Clearance FactorFAIL - MPJ-26 - MPJ-26L1 - MPJ-26L169.598,845.419.594,795.391.1608,845.41Centre DistancePass - MPJ-26 - MPJ-26L2 - MPJ-26L285.278,795.39-24.724,803.860.7758,795.39Clearance FactorFAIL - MPJ-26 - MPJ-26L2 - MPJ-26L269.598,845.419.594,795.391.1608,845.41Centre DistancePass - MPJ-26 - MPJ-26PB1 - MPJ-26PB185.278,795.39-24.724,803.860.7758,795.39Clearance FactorFAIL - MPJ-26 - MPJ-26PB1 - MPJ-26PB169.598,845.419.594,795.391.1608,845.41Centre DistancePass - MPJ-26 - MPJ-26PB2 - MPJ-26PB285.278,795.39-24.724,803.860.7758,795.39Clearance FactorFAIL - MPJ-26 - MPJ-26PB2 - MPJ-26PB269.598,845.419.594,795.391.1608,845.41Centre DistancePass - 16 June, 2020-12:45COMPASSPage 5 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-37i - MPU I-37 wp06Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 800.00 MPU I-37 wp06 3_Gyro-GC_Csg800.00 5,495.39 MPU I-37 wp06 3_MWD+IFR2+MS+Sag5,495.39 15,962.73 MPU I-37 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.16 June, 2020-12:45COMPASSPage 6 of 8 0.001.002.003.004.00Separation Factor5500 6050 6600 7150 7700 8250 8800 9350 9900 10450 11000 11550 12100 12650 13200 13750 14300 14850 15400 15950Measured Depth (1100 usft/in)MPU I-22 wp03MPU I-29 wp03MPJ-22MPI-09MPJ-08AMPJ-08MPJ-25MPJ-09MPJ-26MPI-08WSAK-25No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.WELL DETAILS:Plan: MPU I-37i NAD 1927 (NADCON CONUS)Alaska Zone 0432.20+N/-S +E/-W Northing Easting Latittude Longitude0.000.006009449.42 551569.9770° 26' 11.632 N 149° 34' 46.348 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-37i, True NorthVertical (TVD) Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Measured Depth Reference:MPU I-37 As-Staked Location @ 58.70usft (Original Well Elev)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-06-16T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 800.00 MPU I-37 wp06 (MPU I-37i) 3_Gyro-GC_Csg800.00 5495.39 MPU I-37 wp06 (MPU I-37i) 3_MWD+IFR2+MS+Sag5495.39 15962.73 MPU I-37 wp06 (MPU I-37i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)5500 6050 6600 7150 7700 8250 8800 9350 9900 10450 11000 11550 12100 12650 13200 13750 14300 14850 15400 15950Measured Depth (1100 usft/in)MPJ-08NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 15962.73Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-37iWellbore: MPU I-37iPlan: MPU I-37 wp06Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3773.70 3715.00 5495.39 9-5/8 9 5/8" x 12 1/4"4033.70 3975.00 15962.73 4-1/2 4 1/2" x 8 1/2" 1 Davies, Stephen F (CED) From:Cody Dinger <cdinger@hilcorp.com> Sent:Friday, June 19, 2020 5:41 PM To:Davies, Stephen F (CED); Darci Horner - (C) Cc:Joseph Engel Subject:Re: [EXTERNAL] RE: Milne Point I-37 directional plan HiSteve, HilcorpwillnotpreͲproduce/flowbackMPUIͲ37. GetOutlookforiOS From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Friday,June19,20203:36:55PM To:DarciHornerͲ(C)<dhorner@hilcorp.com>;CodyDinger<cdinger@hilcorp.com> Subject:[EXTERNAL]RE:MilnePointIͲ37directionalplan Darci,Cody: WillHilcorp’splannedinjectionwellMPUIͲ37bepreͲproducedfor30daysorlonger,orwillitbeflowedbackbrieflyfor cleanup? Thanksandstaysafe, SteveDavies AlaskaOilandGasConservationCommission(AOGCC) CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:DarciHornerͲ(C)<dhorner@hilcorp.com> Sent:Friday,June19,20209:07AM To:Davies,StephenF(CED)<steve.davies@alaska.gov>;Boyer,DavidL(CED)<david.boyer2@alaska.gov> Cc:CodyDinger<cdinger@hilcorp.com> Subject:MilnePointIͲ37directionalplan Goodmorning, PleasefindattachedthedirectionalplanforMilnePointinjectorIͲ37.Weanticipatesubmittingthe10Ͳ401latertoday. PleasereachouttomyselforCodyDingerwithanyquestions. Regards, DarciHorner (NorthernSolutions) RegulatoryTechnologist HilcorpAlaska,LLC :(//3(50,7&+(&./,67&RPSDQ\+LOFRUS$ODVND//&:HOO1DPH0,/1(3781,7,,QLWLDO&ODVV7\SH6(53(1'*HR$UHD8QLW2Q2II6KRUH2Q3URJUDP6(5)LHOG 3RRO:HOOERUHVHJ$QQXODU'LVSRVDO37'0,/1(32,176&+5$'(5%/))2,/1$ 3HUPLWIHHDWWDFKHG<HV 6XUIORFLQ$'/WRSSURGLQWLQ$'/7'LQ$'/ /HDVHQXPEHUDSSURSULDWH<HV 8QLTXHZHOOQDPHDQGQXPEHU<HV 0LOQH3RLQW6FKUDGHU%OXII2LO3RROJRYHUQHGE\&2DPHQGHGE\&2 :HOOORFDWHGLQDGHILQHGSRRO<HV &2VSHFLILHV³7KHUHDUHQRUHVWULFWLRQVDVWRZHOOVSDFLQJH[FHSWWKDWQRSD\VKDOO :HOOORFDWHGSURSHUGLVWDQFHIURPGULOOLQJXQLWERXQGDU\<HV EHRSHQHGLQDZHOOFORVHUWKDQIHHWIURPWKHH[WHULRUERXQGDU\RIWKHDIIHFWHGDUHD´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aniel T. Seamount, Jr.Digitally signed by Daniel T. Seamount, Jr. Date: 2020.06.29 09:20:05 -08'00'JMP6/29/2020