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220-060
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 6, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC I-39 MILNE PT UNIT I-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2024 I-39 50-029-23686-00-00 220-060-0 W SPT 3786 2200600 1500 494 497 496 500 4YRTST P Sully Sullivan 10/7/2024 Monobore well 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-39 Inspection Date: Tubing OA Packer Depth 272 1746 1685 1665IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241009142309 BBL Pumped:2.7 BBL Returned:2.7 Friday, December 6, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.12.06 11:21:16 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Milne Point MIT"s and Caliper for MPF-13, MIT-IA for MPI-39 Date:Monday, October 21, 2024 2:23:20 PM Attachments:MPF-13_MFC40_15Oct2024 Integrity Report.pdf MIT-T MPU F-13 10-17-24.xlsx MIT-IA MPU F-13 10-7-24.xlsx MIT-IA MPU I-39 10-7-24.xlsx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, October 18, 2024 11:14 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: Milne Point MIT's and Caliper for MPF-13, MIT-IA for MPI-39 All, Please find attached: MPF-13 (PTD# 195027) MIT-IA, MIT-T & Caliper report per AIO 10B.009. MPI-39 (PTD# 2200600) MIT-IA Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2200600 Type Inj W Tubing 494 497 496 500 Type Test P Packer TVD 3787 BBL Pump 2.7 IA 272 1746 1685 1665 Interval 4 Test psi 1500 BBL Return 2.7 OA Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp Alaska LLC Milne Point / MPU / I Sean Sullivan Jess Hall 10/07/24 Notes:Monobore injector, no OA. Notes: Notes: Notes: I-39 Form 10-426 (Revised 01/2017)MIT-IA MPU I-39 10-7-24 MEMORANDUM TO: Jim Regg�, to) Z°( zr � P.I. Supervisor `'i, FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Monday, October 26, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 1-39 MILNE PT UNIT 1-39 Src: Inspector Reviewed By.:�pp P.I. Supry _12,V— Comm Well Name MILNE PT UNIT 1-39 API Well Number 50-029-23686-00-00 Inspector Name: Matt Herrera Permit Number: 220-060-0 Inspection Date: 10724/2020 - IBsp Num: mitMFH2O1024160239 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-39 Type IBj I w TVD 1 3787 Tubing -M- 609 1 609 609 - PTD 2200660 Type Test sPT- Test psi 1500 IA 83 1593 1530 - 1512 - BBL Pumped: 2.2 - IBB OA Interval INITAL Notes: Initial MIT -IA IA Pressure tested to 1600 PSI per Operator. Monobore Completion No OA Monday, October 26, 2020 Pa�'e I of DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23686-00-00Well Name/No. MILNE PT UNIT I-39Completion Status1WINJCompletion Date9/2/2020Permit to Drill2200600OperatorHilcorp Alaska, LLCMD16994TVD4005Current Status1WINJ10/16/2020UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, AGR, ABG, DGR, EWR, ADR MD & TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF10/5/2020114 16994 Electronic Data Set, Filename: MPU I-39 LWD Final.las34035EDDigital DataDF10/5/20206953 16956 Electronic Data Set, Filename: MPU I-39 ADR Quadrants All Curves.las34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final MD.cgm34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final TVD.cgm34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39i - Definitive Survey Report.pdf34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39i Final Surveys.xlsx34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39i_DSR.txt34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39i_GEO.txt34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final MD.emf34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final TVD.emf34035EDDigital DataDF10/5/2020 Electronic File: MPU_I-39_Geosteering.dlis34035EDDigital DataDF10/5/2020 Electronic File: MPU_I-39_Geosteering.ver34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final MD.pdf34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final TVD.pdf34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final MD.tif34035EDDigital DataDF10/5/2020 Electronic File: MPU I-39 LWD Final TVD.tif34035EDDigital DataFriday, October 16, 2020AOGCCPage 1 of 2MPU I-39 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23686-00-00Well Name/No. MILNE PT UNIT I-39Completion Status1WINJCompletion Date9/2/2020Permit to Drill2200600OperatorHilcorp Alaska, LLCMD16994TVD4005Current Status1WINJ10/16/2020UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:9/2/2020Release Date:7/29/20200 0 2200600 MILNE PT UNIT I-39 LOG HEADERS34035LogLog Header ScansFriday, October 16, 2020AOGCCPage 2 of 210/16/2020M. Guhl 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-39 (PTD 220-060) FINAL LWD LOGS (29AUG2020): EWR-M5, AGR, ADR, DGR, ABG, WELLBORE_PROFILE (MD/TVD) AND DEFINITIVE DIRECTIONAL SURVEY Final CD Folders: Received by the AOGCC 10/05/2020 PTD: 2200600 E-Set: 34035 Abby Bell 10/05/2020 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 33.60' 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-25 115' L-80 1922' L-80 3801' 4-1/2" L-80 3922' 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 6673'3-1/2" 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 - 700 sx / T - 269 sx Driven Surface 2430' Stg 1 L - 629 sx / T - 408 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 9/2/2020 2340' FSL, 3921' FEL, Sec. 33, T13N, R10E, UM, AK 1917' FNL, 666' FEL, Sec. 20, T13N, R10E, UM, AK 220-060 Milne Point Field, Schrader Bluff Oil Pool 60.25' 15885' / 3922' HOLE SIZE AMOUNT PULLED 33.60' 50-029-23686-00-00 MPU I-39 551450 6009454 1196' FNL, 2326' FWL, Sec. 32, T13N, R10E, UM, AK CEMENTING RECORD 6011170 SETTING DEPTH TVD 6021021 BOTTOM TOP Surface Surface CASING WT. PER FT.GRADE 13.5# 547121 549315 TOP SETTING DEPTH MD Surface 6774' Per 20 AAC 25.283 (i)(2) attach electronic information 40# 15885' 1922' 3786' DEPTH SET (MD) 6774' / 3786' PACKER SET (MD/TVD) 130# 47# 115' 2430' 6963' 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 8/30/2020 ***Please see attached Schematic for detail*** ROP, AGR, ABG, DGR, EWR, ADR MD & TVD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 8/27/2020 8/14/2020 ADL 025906, 025517 & 025515 88-004 2176' / 1775' N/AN/A None 16994' / 4005' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 10:53 am, Sep 28, 2020 Completion Date 9/2/2020 MDG RBDMS 10/13/2020 MDG GSFD 10/15/2020 DSR-10/14/2020MGR15OCT2020 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 35' 35' 2211' 1810' Top of Productive Interval 6820' 3791' 1441' 1351' 2570' 1992' 5196' 3263' 6600' 3765' 6820' 3791' SB NB 6820' 3791' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Joe Lastufka Contact Email:joseph.lastufka@hilcorp.com Authorized Contact Phone: 777-8400 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager SB NB Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Permafrost - Top SB NA SV5 SV1 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: Ugnu LA3 LOT / FIT Data Sheet, Drilling and Completion Reports, Csg and Cmt Report, Definitive Directional Survey, Wellbore Schematic Signature w/Date: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 9.28.2020Digitally 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: 2020.09.28 10:00:24 -08'00' Monty M Myers _____________________________________________________________________________________ Revised By: JNL 9/21/20 Schematic Milne Point Unit Well: MPU I-39 PTD: 220-060 API: 50-029-23686-00-00 4-1/2” SOLID Liner Detail 4-1/2” SCREEN Liner Detail Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 3 6816’ 3791’ 6939’ 3801’ 11 6981’ 3801’ 7431’ 3808’ 8 7474’ 3809’ 7795’ 3808’ 25 7837’ 3806’ 8839’ 3848’ 11 8881’ 3850’ 9322’ 3835’ 14 9363’ 3833’ 9925’ 3805’ 11 9967’ 3805’ 10407’ 3820’ 13 10449’ 3822’ 10964’ 3845’ 14 11006’ 3847’ 11575’ 3865’ 5 11617’ 3866’ 11822’ 3872’ 8 11864’ 3872’ 12190’ 3873’ 9 12232’ 3874’ 12602’ 3882’ 21 12644’ 3883’ 13495’ 3903’ 12 13537’ 3904’ 14015’ 3907’ 9 14057’ 3907’ 14416’ 3909’ 7 14458’ 3909’ 14739’ 3914’ 8 14781’ 3915’ 15102’ 3914’ 9 15144’ 3913’ 15512’ 3917’ 6 15554’ 3918’ 15800’ 3922’ 1 15842’ 3922’ 15883’ 3922’ Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 1 6939’ 3801’ 6981’ 3801’ 1 7431’ 3808’ 7474’ 3809’ 1 7795’ 3808’ 7837’ 3806’ 1 8839’ 3848’ 8881’ 3850’ 1 9322’ 3835’ 9363’ 3833’ 1 9925’ 3805’ 9967’ 3805’ 1 10407’ 3820’ 10449’ 3822’ 1 10964’ 3845’ 11006’ 3847’ 1 11575’ 3865’ 11617’ 3866’ 1 11822’ 3872’ 11864’ 3872’ 1 12190’ 3873’ 12232’ 3874’ 1 12602’ 3882’ 12644’ 3883’ 1 13495’ 3903’ 13537’ 3904’ 1 14015’ 3907’ 14057’ 3907’ 1 14416’ 3909’ 14458’ 3909’ 1 14739’ 3914’ 14781’ 3915’ 1 15102’ 3914’ 15144’ 3913’ 1 15512’ 3917’ 15554’ 3918’ 1 15800’ 3922’ 15842' 3922’TD =16,994’ (MD) / TD =4,005’ (TVD) 20” Orig. KB Elev.:60.25’/ GL Elev.: 33.6’ 3-1/2” 2 9-5/8” 1 3/4 7 See Screen Joint Detail PBTD = 15,885’ (MD) / PBTD = 3,922’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,452’ MD 4-1/2” 5/6 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 130 / X-25 / Weld N/A Surface 115’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 2,430’ 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.679” 2,430’ 6,963’ 0.0758 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.920” 6,774’ 15,885’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / TXP-SR 2.867” Surf 6,673’ 0.0870 OPEN HOLE / CEMENT DETAIL 12-14”Stg 1 –Lead 629 sx / Tail 408 sx Stg 2 –Lead 700 sx / Tail 269 sx 8-1/2” Cementless Injection Liner WELL INCLINATION DETAIL KOP @ 243’ MD Hole Angle @ XN = 69 ° Hole Angle @ Liner Top = 84° Max Hole Angle = 94° 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#: 50-029-23686-00-00 Completed by Innovation: 9/2/2020 JEWELRY DETAIL No Top MD Item ID Upper Completion 1 6052’ 3-1/2” C6 Gauge 400 BAR 150C w/ ¼” Wire 2.992” 2 6105’ 3-1/2” XN Nipple. 2.75” No Go, 2.813” profile 2.750” 3 6775’ 8.26” No Go Locater + Cross Over Sub 3.960” 4 6777’ Tieback Seal Assy to No Go Locator 6.180” 5 6780’ HRD-E ZXP Liner Top Packer SBR 7.390” Lower Completion 6 6774’ 7” x 9-5/8” SLZXP Liner Top Packer 6.190” 7 15885’ Shoe CASING AND LEAK-OFF FRACTURE TESTS Well Name:MPU I-39 Date:8/23/2020 Csg Size/Wt/Grade: Supervisor:Barber / Montague Csg Setting Depth:6,963 3,801 TVD Mud Weight:8.9 ppg LOT / FIT Press =645 psi LOT / FIT =12.16 ppg Hole Depth =6993 md Fluid Pumped=1.5 Bbls Volume Back =1.4 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 ->226 ->10 273 ->461 ->20 557 ->6109 ->30 802 ->8176 ->40 1059 ->10 246 ->50 1328 ->12 318 ->60 1609 ->14 392 ->70 1889 ->16 452 ->80 2168 ->18 511 ->90 2457 ->20 567 ->98 2686 ->22 618 -> ->23 645 -> -> -> Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0.5 645 ->02686 ->1609 ->12667 ->1.5 601 ->22665 ->2595 ->32664 ->3583 ->42663 ->4571 ->52661 ->5562 ->10 2656 ->6554 ->15 2650 ->7545 ->20 2647 ->8538 ->25 2643 ->9532 ->30 2640 ->10 524 -> -> -> -> -> 9.625 40#/47# L-80 0 2 4 6 8 10 12 14 16 18 202223 0 10 20 30 40 50 60 70 80 90 98 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 102030405060708090100110Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 645609601595583571562554545538532524 268626672665266426632661 2656 2650 2647 2643 2640 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 8/12/2020 PJSM N/U Dry Hole Tree as per NOS. Test Hanger void 500 PSI low 5 min, 5,000 PSI high 10 min. Test Tree 250/ 5,000 PSI low 5 min. Pull CTS. SIMOPS: Cont PM's on MP's. Bridle up. Blow Down steam, air & H2O. Prep Pipe Shed. Went on Gen Power 08:30. Rig released at 06:00.;PJSM Scope down Derrick. Went to cold start at 10:30. Remove cutting box. Disconnect interconnects. Prep Pipe Shed and Gen Mod. Spot Break Shack & Enviro Vac. Prep Shop for move. Raise and safe stairs and landings. Remove out riggers. Peak trucks on location @ 11:30. SIMOPS LRS Freeze Protect I-38;22 bbls Diesel 2 bpm 500 PSI, IA 70 bbls Diesel 2 bpm 520 PSI.;PJSM Perform pre rig move inspection. Remove steam trap disc. Pull rig matts and install jeep on Gen & Mud Mod, spot. on pad. Jack up spot Pipe Shed and Catwalk. Walk Sub off I-38 and walk to I-39. Install Slip Loc Head, Diverter adapter and Diverter Tee on I-39. Stage Tree and RCD behind well.;Walk Sub over I-39. Observed keeper bolts sheared on frame pins in Sub base. Installed new bolts. Level Sub. Spot Catwalk to Sub.;PJSM Cont spotting Catwalk and shim. Spot and shim Pipe Shed, Mud & Gen Mod. Spot Break Shack and Enviro Vac. Peak released at 04:30. Hook up inner connects, cont rigging up.;Daily fluid to G&I 0 bbls total = 0 bbls Daily water from A Pad Lake 0 bbls total =0 bbls Daily water from B pad creek 0 bbls total =0 bbls Daily water from L pad lake 0 bbls total=0 bbls Daily water from G pad lagoon 0 bbls total = 0 bbls 8/13/2020 Finish shimming sub and pipeshed modules. Swap to rig power (C32 @ 07:00 hrs). Set cuttings box and MPD shacks. Roll steam, water and air throughout rig. Work rig acceptance checklist. AOGCC notification sent via email @ 07:14 hrs. Witness waived by AOGCC rep Jeff Jones via email.;PJSM, Scope and pin derrick. R/U handling equipment and prep for drilling operations. Bridal down. Load 290 bbls 8.8 spud mud in pits. Dress shakers w/ 100's.;PJSM, M/U working jt and set in slips (secure w/ dog collar). Hang blocks and M/U snake from new to old drilling line. Remove drilling line from deadman, remove crown saver from static deadman line and secure same.;Disable crown saver switch. Inspect spooling unit and snake connection (good). Slip new drilling line on traveling equipment and drawworks. Secure line on deadman. Install crown saver on static deadman line. Enable crown saver switch. Discard spent line.;N/U 13-5/8" BOP stack, configured for diverter operations drilling surface. N/U 16" diverter knife valve, 16" diverter line to tundra and PT. PT Slip Lock Packing to 500 psi, good test, install Riser Continue w ork rig acceptance checklist;Accept Rig at 00:00, Hazard Hunt for oncoming crew, PJSM P/U M/U 5” S-135 NC-50 DP M/U stands in mouse hole and rack back, drift w/ 3.125” rabbit F/ Skate P/U – 107 stands;Daily fluid to G&I 0 bbls total = 0 bbls Daily water from G pad lagoon 650 bbls total = 650 bbls 8/14/2020 PJSM P/U M/U 5" D.P. and rack back in Derrick total 107 stands. Drift 3.125" OD. P/U M/Y 5" HWDP rack back in Derrick 8 stands and Jar Stand. Drift 2.75" OD.;PJSM Perform Diverter test witnessed waived by Jeff Jones. Knife Valve- 7 sec, Annular- 9 Sec, System Press 3,030 PSI, After function 1,850 PSI. 200 PSI inc 17 sec, full charge 59 psi, Average Nitrogen Press 3,000 PSI.;PJSM Grease & inspect Crown & Top Drive.;PJSM P/U M/U clean out BHA 12.25" KMX633 Hybrid and 8" SperryDrill 4/5- 5.3 stg 1.5° motor.;PJSM Spud Well. Flood conductor W/ 8.9 ppg Spud Mud. No leaks on surface Equip. Wash down tag at 48' MD. Cont washing down to shoe at 115' MD. Drill ahead F/ 115' to 219' MD. 330-450 GPM, 297-500 PSI, 40 RPM, TRQ 1K, WOB 1K,, P/U 48K, SLK 46K ROT 47K.;BROOH F/ 219' to 125' MD 400 GPM, 500 PSI, 40 RPM, TRQ 1-2K. Pumped out F/ 125' to 98' MD. no issue at shoe. POOH on elevators F/ 98' to surface.;PJSM Inspect bit 3 BT &1 CT on face. P/U M/U 8" DM GWD, 8" EWR-M5, ILS, 8" DM Collar, 8" TM Collar, UBHO. RFO 7.87/7.92=357.7°. DM to Gyro RFO 0.15/7.86=6.9° witnessed by Co Rep, DD, MWD & Gyro. Plug in and download MWD.;PJSM Drill 12.25" Surface Hole F/219' to 598' MD ( 596' TVD) Total 379’ (AROP 69’) 400 GPM, 720 PSI, 40 RPM, TRQ on 1.5K, TRQ off 1K, WOB 1-4K. P/U 64K, SLK 66K, ROT 66K. Max Gas 6U. ECD 9.5. Start KO @ 222' 3°/100;PJSM Drill 12.25" Surface Hole F/598' to 1104'MD ( 1082' TVD) Total 506’ (AROP 84’) 450 GPM, 1260PSI, 60 RPM, TRQ on 3.5K, TRQ off 2.3K, WOB 8K. P/U 79K, SLK 77K, ROT 76K. Max Gas 22U, ECD 9.8. ROT Hrs 1.39, SLD Hrs 4.47;Distance to WP #9 3.06', 1.56' high, 2.67' Left;Daily fluid to G&I 285 bbls total = 285 bbls Daily water from G pad lagoon 260 bbls total = 910 bbls 8/15/2020 PJSM Drill 12.25" Surface Hole F/ 1,104' to 1,613'MD (1,479' TVD) Total 509’ (AROP 84.8’) 450 GPM, 1,350 PSI, 60 RPM, TRQ on 5K, TRQ off 3.4K, WOB 8-10K, F/O 57%. P/U 89K, SLK 79K, ROT 84K. Max Gas 149U, ECD 9.7 W/ 9.1 MW 220 Vis. Sliding as needed for 4°/100 build. Back ream 30'. Clean MWD @ 700';PJSM Drill 12.25" Surface Hole F/ 1,613' to 2,186'MD (1,796' TVD) Total 573’ (AROP 95.5’) 450-485 GPM, 1,530 PSI, 60-80 RPM, TRQ on 6.5K, TRQ off 5.5K, WOB 8-10K, F/O 62%. P/U 96K, SLK 72K, ROT 83K. Max Gas 630U, ECD 10.22 W/ 9.2 MW 200 Vis. Sliding as needed for 4°/100 build. Back ream 30'.;1.0° Inc, building to 60.4 deg Inc +2.0 deg to 62.4 for the SV2 at 2080' MD, Started Tangent at 2,087' MD;Drill 12.25" Surface Hole F/ 2186' to 2,817'MD (2,117' TVD) Total 631’ (AROP 105’) 450 GPM, 1520 PSI, 60-90 RPM, TRQ on 7K, TRQ off 6.5K, WOB 8K, F/O 58%. P/U 100K, SLK 73K, ROT 87K. Max Gas 1793U, ECD 10.13 W/ 9.2 MW 320 Vis. Cont 60° Tangent;2627' MD starting to see an increase in Gas Units during connections. 2645' MD Gas Units at 1200, 2673' Gas Units at 1815, slow down pump rate and ROP to keep mud on shakers, Back ream full stands;Drill 12.25" Surface Hole F/ 2,817' to 3331'MD (2365' TVD) Total 514’ (AROP 86’) 450 GPM, 1685PSI, 90 RPM, TRQ on 8K, TRQ off 7K, WOB 8-10K, F/O 62%. P/U 104K, SLK 74K, ROT 89K. Max Gas 464U, ECD 11.0 W/ 9.3 MW 240 Vis. ROT 5.62 hrs, SLD 7.31 hrs.;Caught SVO sample at 2970' MD 2190' TVD, samples showed very little heavy tar, MW F/2600' 9.35 ppg, Back ream full stands.;Distance to WP #9 12.41', 2.78' high, 12.09' Left;Daily fluid to G&I 969 bbls total = 1254 bbls Daily water from G pad lagoon 260 bbls total = 910 bbls 50-029-23686-00-00API #: Well Name: Field: MP I-39 Milne Point Hilcorp Energy Company Composite Report 8/14/2020Spud Date: 8/16/2020 Drill 12.25" Surface Hole F/ 3,331' to 3,904'MD (2,649' TVD) Total 573’ (AROP 95.5’) 500 GPM, 1,675 PSI, 80 RPM, TRQ on 9-10K, TRQ off 9K, WOB 3K, F/O 59%. P/U 122K, SLK 78K, ROT 97K. Max Gas 451U, ECD 10.1 W/ 9.3 MW 110 Vis. Maintain Tangent 60° Inc 274° Azi. Back ream 60'.;Drill 12.25" Surface Hole F/ 3,904' to 4,413'MD (2,894' TVD) Total 509’ (AROP 84.8’) 525 GPM, 1,930 PSI, 80 RPM, TRQ on 11K, TRQ off 10K, WOB 8K, F/O 63%. P/U 130K, SLK 80K, ROT 101K. Max Gas 143U, ECD 9.98 W/ 9.3 MW 100 Vis. Back ream full stands.;MPU I-12 Close with 186.1' cc at 3,700' MD 1.33° separation factor from 3,700' to 3,900' MD Plan 4.0°/100' turn from 273.8° Azi to 282.5° Azi from 4,096' to 4,287' MD. Turn 35' slide at 80 Rt TF from 4,029' MD T/4,287' completed turn 4.4°/100 rate 8°/100;Drill 12.25" Surface Hole F/ 4,413' to 4,891'MD (3,119' TVD) Total 478’ (AROP 79.7’) 550 GPM, 2070 PSI, 100 RPM, TRQ on 12.5K, TRQ off 11K, WOB 10K, F/O 68%. P/U 143K, SLK 84K, ROT 106K. Max Gas 124U, ECD 10.1 W/ 9.3 MW 103 Vis. Back ream full stands;Lost both pumps, reset and back online;Drill 12.25" Surface Hole F/ 4,891' to 5,431'MD (3,354' TVD) Total 541’ (AROP 90’) 550 GPM, 2081 PSI, 100 RPM, TRQ on 13.5K, TRQ off 14K, WOB 8K, F/O 59%. P/U 154K, SLK 80K, ROT 109K. Max Gas 408U, ECD 9.9 W/ 9.3 MW 100 Vis. Back ream full stands;End tangent at 5,100' MD, I-14 325' CC @ 4700' MD, F/5100' build/turn 4°/100. Adjusting RPM's 80-100 due to stick/slip, minimal at report time;01:35 Lost both pumps again, online and went down again, reset and online 01:45 Fault - Over Current. 02:25 Lost pumps, #1 Over Heat, #2 Over Current, TP calling out Electrician;Distance to WP #9 11.89', 1.81' high, 11.75' Left;Daily fluid to G&I 1231 bbls total = 2485 bbls Daily water from G pad lagoon 1170 bbls total = 3120 bbls 8/17/2020 Drill 12.25" Surface Hole F/ 5,431' to 5,781'MD (3,117' TVD) Total 350’ (AROP 58.3') 550 GPM, 2,200 PSI, 80 RPM, TRQ on 15.5K, TRQ off 15K, WOB 10K, F/O 64%. P/U 158K, SLK 82K, ROT 112K. Max Gas 420U, ECD 10.0 W/ 9.3 MW 100 Vis. Back ream full stands Cont Build turn 4.5°/100;Drill 12.25" Surface Hole F/ 5,781' to 6,192' to MD (3,687' TVD) Total 403’ (AROP 67.2') 550 GPM, 2,050 PSI, 80 RPM, TRQ on 16K, TRQ off 15K, WOB 2-8K, F/O 64%. P/U 169K, SLK 77K, ROT 115K. Max Gas 650U, ECD 9.95 W/ 9.3 MW 100 Vis. Back ream full stands Cont Build turn 4.5°/100;6344' MD Survey DLS at 9.2°, rack back 1 stand and ream 2x F/6,385' MD T/6,322' MD @ 60 RPM Drill Fault #1 @ 6108' w/ ~40' DTN throw;Drill 12.25" Surface Hole F/ 6,192' MD to 6,513' to MD (3,766' TVD) Total 321’ (AROP 53.5') 500 GPM, 1900 PSI, 80 RPM, TRQ on 18K, TRQ off 18.5K, WOB 7-10K, F/O 60%. P/U 176K, SLK 74K, ROT 113K. Max Gas 554U, ECD 9.91 W/ 9.3 MW 100 Vis. Back ream full stands Cont Build turn 4.5°/100;Drill 12.25" Surface Hole F/ 6,513' - T/ 6767' MD (3801' TVD) Total 254’ (AROP 42') 500 GPM, 1864 PSI, 80 RPM, TRQ on 17.5K, TRQ off 18K, WOB 10K, F/O 60%. P/U 176K, SLK 77K, ROT 113K. Max Gas 220u, ECD 9.9 W/ 9.3 MW 100 Vis. Back ream full stands Cont Build turn 4.5°/100;Distance to WP #9 - 23.94' CC, 19.91' Low, 13.19' Left;Daily fluid to G&I 1088 bbls total = 3573 bbls Daily water from G pad lagoon 1170 bbls total = 4290 bbls 8/18/2020 Drill 12.25" Surface Hole F/ 6,767' - T/ 6973' MD (3819' TVD) Total 206’ (AROP 69') 550 GPM, 2127 PSI, 80 RPM, TRQ on 19K, TRQ off 18K, WOB 10K, F/O 60%. P/U 180K, SLK 72K, ROT 109K. Max Gas 383u, ECD 9.9 W/ 9.3 MW 100 Vis. Top of NB @ 6820' MD. Build to 91° projected @ TD in the NB sand.;Obtain final survey, mode switch to OMM (Outrun Multishot Mode). Circulate and condition hole F/ 6973' - T/ 6710' MD. 550 gpm, 2225 psi, 80 rpm, 16k tq, max gas 1050u B/U, 50u BGG. 9.3 MW w/ 9.9 ECD (74 vis). Pumped 34 bbl hi vis sweep, back on time w/ no increase. 182k up, 72k dn, 109k rot.;RIH on elevators F/ 6710' back to btm @ 6973' without issue. 72k dn, 184k up.;Monitor well (static). BROOH F/ 6973' - T/ 6793' MD. L/D top sgl of std #96 to offset GWD surveys and bring MWD vs GWD survey stations closer for QC comparisons. 550 gpm, 2220 psi, 80 rpm, 16k tq, 9.9 ECD. 20-25 ft/min pulling speed.;Cont. BROOH from 6793' to 4317' at 550 gpm, 2000 psi, 80 rpms, 12Kft-lbs. Max gas 180U, ECD 10.33 with 9.4 ppg mud. PUW 150K, SOW 75K, ROTW 110K, pulling 10-30 fpm as hole dictates.;Cont. BROOH from 4317' to 1963' at 550 gpm, 1600 psi, 80 rpms, 5-9Kft-lbs. Max gas 140U, ECD 10.07 with 9.4 ppg mud. PUW 100K, SOW 68K, ROTW 82K, pulling 10-40 fpm as hole dictates. Slow pulling speed 2 stands prior to base of Permafrost to obtain 2x bottoms up.;Cont. BROOH from 1963' to 723'; 500 gpm, 1200 psi, 40 rpms, 3.5Kft-lbs. Slow rotary to 60 rpms at 1400' (<40° inc) and 40 rpms at 1000' (<25° inc), Max gas 70U, ECD 10 with MW 9.4 ppg. PUW 76K, SOW 76K, ROTW 76K, pulling 2-15 fpm as hole dictates, due to erratic torque. Monitor well at HWDP, static;POOH on elevators from 723' to 162' racking back HWDP. PUW 55K, SOW 54K, no issues.;L/D BHA. L/D (2) flex collars to 101'.;Distance to WP#9 19.02', 18.89' Low, 1.3' Left;Daily fluid to G&I 803 bbls total = 4376 bbls Daily water from G pad lagoon 780 bbls total = 5070 bbls Daily fluid lost 0 bbls, total = 0 bbls 8/19/2020 Download MWD recorded data. L/D MWD tools. Drain mtr assy. B/O and L/D mtr/bit. Bit grade PDC - 2,4,BT,N,X,I,CT,TD / Cone grade - 1,2,LT,G,F,N,NO,TD. Clean and clear rig floor. Damage noted on BHA - Top ILS stab, Btm stab PDM. Pics in "O" drive.;Grease traveling equipment, Crown, Blocks and TDS.;PJSM, R/U bail extensions, 9-5/8" 250T side doors. Stage casing slips, R/U double stack power tongs. Stage 87 bow spring centralizers on floor.;PJSM, M/U shoe track (flashlight floats / good), install "top hat" in float jt. Bakerlok shoe track connections and check floats (good). RIH w/ 9-5/8", 40#, TXP BTC casing F/ surface to 401' MD. Fill every 5. 47k up, 46k dn.;RIH w/ 9-5/8", 40#, TXP BTC casing F/ 401 - T/ 1580' MD. Tagged ledge 3x @ 1580' w/ 35k.;Work thru ledge @ 1580' - 1595' MD. Work thru w/ 10 rpm, 5k free tq, 4 bpm, 80 psi. Saw multiple 15k stalls w/ packoff 200 psi avg. Worked past obstruction @ 1580' and washed next 2 jts down slowly, staged up to 6 bpm, 110 psi. Saw mostly clay w/ sand back at shakers (~1580' / SV1).;Continue RIH w/ 9-5/8" casing F/ 1595' - T/ 2571' MD as per detail. 21k tq on connections. Fill every 5 jts. No issues.;Circulate and condition mud @ 2571' MD (Rot/Recip). Stage up to 6 bpm, 145 psi, 8 bpm, 187 psi, 10 rpm, 4.5k tq. No losses. Circulate 1.5x btms up.;Continue RIH w/ 9-5/8",40# L-80 TXP casing F/ 2571' - T/ 4490' MD as per detail. 21k tq on connections. Fill every 5 jts. M/U ES cementer and Bakerlok. Continue to RIH 2/ 9-5/8", 47#, L-80, TXP casing from 4490' to 5144', 23.8Kft-lbs tq on connections. Fill every 5jts. No issues.;Circulate and condition mud at 5,144'. Stage pumps up to 7 bpm, 290 psi, reciprocating pipe, 1-3 rpms, 15K-ftlbs (torque limiter set point). CBU.;Continue to RIH 2/ 9-5/8", 47#, L-80, TXP casing from 5144' to 6963', 23.8Kft-lbs tq on connections. Fill every 5jts. No issues.;Circulate and condition mud, lowering YP below 20, stage pumps up to 6.5 bpm 257 psi, reciprocating pipe, rotating 1-3 rpms with Tq limiter set at 15Kft-lbs. PUW 255K, SOW 95K.;Daily fluid to G&I 228 bbls total = 4604 bbls Daily water from G pad lagoon 390 bbls total = 5460 bbls Daily fluid lost 31 bbls, total = 31 bbls 8/20/2020 Perform 1st stage cmt job - Wet lines w/ 5 bbls H2O. P/T lines 1250 psi low / 4075 psi high (test good). Pump 58 bbls 10# spacer (5# poly flake, 4# red dye in first 10bbls), 4.5 bpm 440 psi. Drop btm bypass plug. 263 bbls 12# type I/II Lead cmt (2.347 yld) 630sxs, 4.8 bpm, 240 psi. 84 bbls 15.8# Class G Tail cmt (1.155 yld) 400 sxs, 4 bpm, 804 psi. Drop top shutoff plug. HES pump 20 bbls H2O, 5 bpm, 366 psi. Rig disp MP#1 - 303.5 bbls 9.4 spud mud, 8 bpm, 480 psi. HES- 80 bbls 9.4 ppg tuned spacer, 6 bpm, 380 psi (10 bbl below / 70 bbl above stg tool) Rig disp 123 bbls 9.4 spud mud, 8 bpm, 1110 psi. Slowed last 10 bbls to 3 bpm, FCP 640 psi. No bump @ 50% shoe track. Brought pumps on @ 4 bpm and bumped @ 6878 stks (512.8 bbls calc / 526.4 bbls act). Psi up to 1270 psi w/ 5 min hold. Bled back 3 bbls, floats held. CIP @ 11:22 hrs Good returns thru out job w/ 16 bbls total lost. Rot/Recip until last 98 bbls disp. Poly back at shaker 303 bbls into displacement. Psi up @ 4 bpm. Observed indication of stg tool shifting @ 2950 psi. Stg up to 6. bpm, 480 psi. Overboard 146 total bbls contaminated mud w/ spacer, 6 bbls green cmt, Flush surface equipment, Cont circ. Prep for 2nd stg. Circ @ 6 bpm 540 psi. Surge @ 10 bpm holding 2-5 min then continue @ 6 BPM to help cleanup. Surges brought back contaminated mud, cont to circulate hole at 6 bpm, 540 psi with no losses, prepping pits for 2nd stage cement job and WOC. 2nd stage cement job. HES pump 5 bbls H2O 4 bpm, 480 psi. 55 bbls 10# spacer (5# poly flake, 4# red dye in first 10bbls), 4 bpm 480 psi. 154 bbls 10.7# ArcticCem w/ 4k28 beads Lead cmt (2.883 yld) 300sxs, 5.5 bpm 661 psi. 210 bbls 10.7# ArcticCem w/ 4000 beads Lead cmt (2.944 yld) 400sxs, 4 bpm 437 psi Observe good 10.7 ppg cement at surface 349 bbls into lead. 56 bbls 15.8 ppg Class G tail cement (1.169 yld), 269 sxs at 4 bpm, 437 psi. Drop closing plug. Displaced with 20 bbls H2O at 6 bpm, 355 psi. Rig displaced with 170 bbls (159.8 calc) of 9.5 ppg mud at 7 bpm, 855 psi. Slow to 3 bpm with 15 bbls to go. FCP 500 psi. Bump plug and pressure up to 1800 psi, observing tool shift close at 1572 psi. Hold pressure for 5 minutes, bleed back 1 bbls and confirm tool closed. CIP at 21:35. 251 bbls of green cement returned. No losses. R/D cement lines and flush with black water down the bleeder. B/D cement line. disconnect knife valve, fill and flush stack 3x, cycle annular 4x each flush. Break out and L/d Volant tool. SimOps: Disconnect diverter vent line. Install casing elevators. Clean out cellar box. Blow down lines to stack, clean out cellar box. Break bolts and lift stack. Center casing and set 'E-slips (115K on slips). Suck out cut joint. Cut excess casing (29.75') and lay down. Remove casing elevators and install 5". Set stack down and 4-bolt. Pick up working single and stack washing tool. Wash stack with black water. Drain stack, clean out cellar box and flow box. Sim Ops Flush lines and pumps in pits. R/D diverter vent line. Break bolts between diverter 'T' and stack. Remove riser, knife valve. P/U stack and unseat spead head off conductor. Rack stack back. Continue cleaning pits. Daily fluid to G&I 1964 bbls total = 6568 bbls Daily water from G pad lagoon 1040 bbls total = 6500 bbls Daily fluid lost 24 bbls, total = 55 bbls 8/21/2020 Continue with removal of diverter T, DSA and speed head from conductor. Continue with cleaning of pits.;Make final cut on 9.625" casing. (21.75" above emergency slips) Remove bell nipple from stack. Clean and clear rig floor of all unnecessary equipment. P/U split bushings, trip nipple, and test plug / wear ring.;Install the T-103 nipple and test connection to 500 psi Low (5 min) / 3800 psi High (10 min) . Good test. Install T-103 tubing spool and test to 500 psi Low (5 min) / 5000 psi High (10 min). Good test Install Test plug as per NOS reps (Run in and Torque 4 lock down screws to 400 ft/ lbs.;Install DSA, spacer spool. Raise MPD head to flow boxy. Set stack on spacer spool/DSA. Install MPD studs, set MPD head on stack. SimOps: continue cleaning pits.;N/U BOP's. Cross chain and center stack. Install choke and kill lines. Hook up Accumulator lines. TQ DSA and MPD head. Install drip pan. Well head rep TQ slip lock head bolts to 400 ft-lbs.;Install hard line from MPD choke to RCD. Install hard line off RCD to drain hose and hole fill lines. M/U return line from MPD choke to flowline. Flood MPD lines and test 250/1250 psi, observe leak on high. C/O hammer union seal and retest - good.;Test BOPE's 250/3000 psi on 5" and 3.5" test joints. Witnessed by AOGCC rep Guy cook. Lower IBOP failed, changeout while continue testing. F/P on HCR choke; grease and function. Check pit high level alrams, PVT sensor, flow paddle, pit and G/L alarms. Test gas alarms.;Test changed out lower IBOP - pass. Accumulator drawdown: Starting pressure 3100 psi, final 1450 psi. First 200 psi recharge 26 seconds, final 98 seconds. (6) N2 at 2358 psi average.;Daily fluid to G&I 382 bbls total = 6950 bbls Daily water from G pad lagoon 520 bbls total = 7020 bbls Daily fluid lost 0 bbls, total = 55 bbls 8/22/2020 Rig down testing equpment. BOLDS, pull test plug and L/D TIW. pump in sub and test joint. B/D choke, kill and top drive.;Install wear bushing: ID 10", length 12.375". Obtain RKB's. Install mousehole.;Trip nipple leaking at RCD clamp. Pull trip nipple, C/O O-ring and re-install. Fill and test - good.;Service rig: grease crown, blocks, top drive, IBOP, drawworks, iron roughneck, spinners. Check oil in top drive, and top drive cradle welds - good.;M/U BHA. Install hyd elevators. M/U motor and bit as per Sperry. RIH with jars and 9 stands HWDP to 592'.;Pick up, drift (3.125") and single in the hole with 5" drill pipe from 592' to 2,437'. PUW 88K, SOW 58K. Calc displacement.;Wash down from 2,437' and tag cement at 2,445'. Drill cement and ES cementer (on depth) to 2,468' at 400 gpm, 550 psi, 30 rpms, 5500ft-lbs, WOB 5K. Work through with no rotary and no rotary/pumps without any issue.;Pick up, drift (3.125") and single in the hole with 5" drill pipe from 2,468' to 4,726'. Continue to RIH out of derrick from 4,726' to 6,805', tag cement stringer. Wash down to 6,810'.;Circulate hole clean, CBU x 1.5 rotating and reciprocating at 400 gpm, 970 psi, 60 rpms, 17-19Kft-lbs. PUW 175K, SOW 70K, ROT 95K. Rack stand back to 6944';Rig up for casing test. Flush and purge air. PT casing to 2500 psi for 30 minutes - good. Pumped 5 bbls bled back 4.9 bbls.;Drill cement, shoe track and 20' of new hole from 6810' to 6993, tagging float equipment on depth. 450 gpm, 1425 psi, 40 rpms, Tq 17.5Kft-lbs, WOB 6-10K. PUW 197K, SOW 69K, ROTW 102K;Displace to 8.9 ppg Baradril-N. Pump 55bbl high vis spacer followed by drilling fluid at 420 gpm, FCP 890 psi, 60 rpms, 15.8Kft-lbs, reciprocating pipe Monitor well, static. Obtain SPR's.;Rig up and perform FIT to 12.0 ppg EMW with 8.9 ppg drilling fluid, 645 psi. 1.5 bbls pumped, 1.4 bbls bled back. Rig down and blow down lines.;POOH 5 stands from 6944' to 6560' - no indication of swabbing. Pump dry job. Continue to POOH to 4026'. PUW 138K, SOW 74K;Daily fluid to G&I 513 bbls total = 7463 bbls Daily water from G pad lagoon 520 bbls total = 7540 bbls Daily fluid lost 0 bbls, total = 55 bbls 8/23/2020 Continue pooh with 5" drill pipe and drill out BHA from 4026' to surface. Rack back 3x stds w/ jars. Lay down excess HWDP. Lay down cleanout assembly. Bit graded 1-1-NO-A-E-I-NO-BHA. 4.9 bbl loss for trip.;Clean and clear rig floor of cleanout bha components and all other unnecessary equipment;P/U and stage all BHA components on rig floor, and in pipe shed.;PJSM, Make up 8.5" bit, MWD drilling package under Sperry direction. Perform download on tool. Good. RIH with HWDP and Jars from derrick to 340'.;Pick up, drift (3.125") and single in the hole with drill pipe from 340' to 6379'. PUW 165K, SOW 68K. Calculated displacement observed;Circulate bottoms up, reciprocating pipe at 450 gpm, 1150 psi.;Monitor well, static. Pull trip nipples, set MPD bearing.;Hang blocks. Cut and slip 69' of drilling line. Check drawworks brakes, good. perform crown sheave and traveling block wobble.;RIH from 6379' to 6952'. Fill pipe and obtain parameters, 450 gpm, 1250 psi, ECD 10.23 ppg, PUW 169K, SOW 60K, ROT 95K.;Wash down from 6952' to 6993'. Drill 8 1/2" Lateral F/6993' - T/ 7670' (677' total, 112fph AROP). WOB 6-16K, 550 gpm, 1945 psi, 130 rpm, 13Kft-lbs tq, 10.4 ppg ECD with 8.9 ppg MW. Max gas 630U. P/U 166K, SOW 68K ROT 96K. Backream full stands. MPD chokes open.;Crossed fault at 7013' with 21' DTN throw, faulting from NB-sands to NC-Clay. Reacquired NB sands at 7408' Increase lubes to 2.5% due to stick slip.;1 fault has been crossed so far (7013') 3 concretions have been drilled so far for a total footage of 10’ (1.6% of the lateral section). Total footage drilled in NB sands = 222', footage out of NB Sand = 395' Distance to well plan WP09 7.0' 1.20' high / 6.90' left;Daily fluid to G&I 805 bbls total = 8268 bbls Daily water from G pad lagoon 260 bbls total = 7800 bbls Daily fluid lost to formation 0 bbls, total = 0 bbls Fluid lost on surface hole = 55 bbls 8/24/2020 Continue to drill 8 1/2" Lateral F/7670' - T/ 8467' (797' total, 132fph AROP). WOB 5-15K, 525 gpm, 1845 psi, 120-140 rpm, 14-17Kft-lbs tq, 11.23 ppg ECD with 8.9+ ppg MW. Max gas 638U. P/U 165K, SOW 65K ROT 95K. Backream full stands. MPD chokes open.;Drilled out of base NB-sand at 7960' in anticipation of fault. Crossed fault at 8385' with 48' DTN, faulting from NC-clay to NB-sand. Crossed fault at 8455' with 50' DTN throw, faulting from NB -sand to UG MF.;Continue to drill 8 1/2" Lateral F/8467' - T/ 9106' (639' total, 107 fph AROP). WOB 11-14K, 525 gpm, 2060 psi, 140 rpm, 18Kft-lbs tq, 11.4 ppg ECD with 9.0 ppg MW. Max gas 535U. P/U 164K, SOW 52K ROT 100K. Backream full stands. MPD chokes open.;Reacquired NB-sands at 8820'. Crossed fault at 9090' with 23 DTS throw, from NB sands to NC clay.;Continue to drill 8 1/2" Lateral F/9106' - T/ 9807' (701' total, 117 fph AROP). WOB 12-15K, 525 gpm, 2220 psi, 140 rpm, 16Kft-lbs tq, 12.1 ppg ECD with 9.1 ppg MW. Max gas 546U. P/U 142K, SOW 56K ROT 96K. Backream full stands. MPD chokes open.;Reacquired NB sand at 9197'. Drilled out top at 9418', and crossed a fault at 9445' with 40' DTS throw from NA clay to NC Clay. Reacquired NB sands at 9740'.;Continue to drill 8 1/2" Lateral F/9807' - T/ 10,177' (370' total, 123 fph AROP). WOB 5-15K, 530 gpm, 2480 psi, 140 rpm, 17.5Kft-lbs tq, 12.3 ppg ECD with 9.1 ppg MW. Max gas 637U. P/U 136K, SOW 52K ROT 92K. Backream full stands. MPD chokes open.;Exited top of NB sand at 10,000', reacquire NB sands at 10,133'.;Troubleshoot Halliburton DD Compass program, showing incorrect verticle section, N/S, E/W. Download original compass well plan and re-enter surveys. Rack stand back and circulate hole while troubleshooting, 510 gpm, 2230 psi, 140 rpms, 13.5Kft-lbs, reciprocating pipe.;Continue to drill 8 1/2" Lateral F/10,177' - T/ 10,312' (135' total, 68 fph AROP). WOB 10K, 500 gpm, 2260 psi, 140 rpm, 15.5Kft-lbs tq, 11.97 ppg ECD with 9.1 ppg MW. Max gas 188U. P/U 142K, SOW 63K ROT 93K. Backream full stands. MPD chokes open.;Pump tandem low vis/wt, high vis/wt sweep at 10,177' (on time 10% increase), lowering ECD from 12.3 ppg to 11.9 ppg.;5 faults has been crossed so far (7013', 8385', 8455', 9090', 9445') 14 concretions have been drilled so far for a total footage of 66’ (2.0% of the lateral section). Total footage drilled in NB sands = 1538', footage out of NB Sand = 1747' Distance to WP09= 46.13' (26.39' High / 37.84' Left);Daily fluid to G&I 684 bbls total = 8952 bbls Daily water from G pad lagoon 780 bbls total = 8580 bbls Daily fluid lost to formation 0 bbls, total = 0 bbls Fluid lost on surface hole = 55 bbls Daily metal 10 lbs. Total= 10 lbs 8/25/2020 Continue to drill 8 1/2" Lateral F/10,312' - T/ 11086' (774' total, 129 fph AROP). WOB 5-15K, 520 gpm, 2415 psi, 140 rpm, 12Kft-lbs tq, 11.9 ppg ECD with 9.1+ ppg MW. Max gas 518U. P/U 148K, SOW 68K ROT 98K. Backream full stands. MPD chokes open.;Increased lubes to 3%. 7k reduction in drilling torque was observed (18k-11k);Continue to drill 8 1/2" Lateral F/11,086' - T/ 11,789' (703' total, 117 fph AROP). WOB 15-17K, 540 gpm, 2480 psi, 120 rpm, 14.5Kft-lbs tq, 11.68 ppg ECD with 9.1+ ppg MW. Max gas 545U. P/U 150K, SOW 56K ROT 100K. Backream full stands. MPD chokes open.;Crossed fault at 11,690 with 10' DTN throw from NB sands to NC clay. Reacquire NB sands at 11,783'.;Continue to drill 8 1/2" Lateral F/11,789' - T/ 12,605' (816' total, 136 fph AROP). WOB 5K, 540 gpm, 2480 psi, 140 rpm, 14.5Kft-lbs tq, 11.83 ppg ECD with 9.0 ppg MW. Max gas 570U. P/U 158K, ROT 99K. Lost slack off weight at 12,161'. Backream full stands. MPD chokes open.;Continue to drill 8 1/2" Lateral F/12,605' - T/ 13401' (796' total, 132 fph AROP). WOB 5-10K, 540 gpm, 2335 psi, 140 rpm,16.7 Kft-lbs tq, 12.2 ppg ECD with 9.0 ppg MW. Max gas 533U. P/U 140K, SOW N/A ROT 95K. Backream full stands. MPD chokes open.;Drilled out base of NB sand at 12,885' for collision avoidance of MP J-25. Reacquire sands at 13,197'. Closest approach at 13,099' with 32.38' center to center.;6 faults has been crossed so far (7013, 8385, 8455, 9090, 9445, 11690) 23 concretions have been drilled so far for a total footage of 123’ (1.9% of the lateral section). Total footage drilled in NB sands = 4188', footage out of NB Sand = 2152' Distance to WP09= 27.19' (27.17' Low / 0.85' Left);Daily fluid to G&I 1589 bbls total = 10521 bbls Daily water from G pad lagoon 1560 bbls total = 10140 bbls Daily fluid lost to formation 0 bbls, total = 0 bbls Fluid lost on surface hole = 55 bbls Daily metal 2 lbs. Total= 12 lbs 8/26/2020 Continue to drill 8 1/2" Lateral F/13,401' - T/ 14,386' (985' total, 164 fph AROP). WOB 5-10K, 515 gpm, 2375 psi, 140 rpm, 17.2 Kft-lbs tq, 12.16 ppg ECD with 9.0+ ppg MW. Max gas 730U. P/U 161K, SOW N/A ROT 92K. Backream full stands. MPD chokes open.;Continue to drill 8 1/2" Lateral F/14,386' - T/ 15,024' (638' total, 106 fph AROP). WOB 10K, 520 gpm, 2435 psi, 130 rpm, 21Kft-lbs tq, 11.7 ppg ECD with 9.0+ ppg MW. Max gas 740U. P/U 173K, SOW N/A ROT 98K. Backream full stands. MPD chokes open.;Encountered losses at 14,500' with initial loss rate of 60 bph, breathing back on connections. Losses slowing to ~4-5 bph, breathing back on connections.;Cont to drill 8 1/2" Lateral F/15,024' to 15,723' (699' total, 117fph AROP). WOB 9K, 520 gpm, 2430 psi, 140 rpm, 20Kft-lbs tq, 11.73 ppg ECD with 9.0ppg MW. Max gas 823U. P/U 193K, SOW N/A ROT 87K. Backream full stands. MPD chokes open. Losing 10-20 bph dynamically, breathing on connections.;Cont to drill 8 1/2" Lateral F/15,723' to 16,421' (698' total, 116fph AROP). WOB 10-20K, 515 gpm, 2585 psi, 140 rpm, 22Kft-lbs tq, 12.11 ppg ECD with 9.0ppg MW. Max gas 771U. P/U 181K, SOW N/A ROT 95K. Backream full stands. MPD chokes open. Losing ~10 bph dynamically, breathing on connections.;Crossed fault #8 with 24' DTN from NB -sand to NA-Clay.;6 faults has been crossed so far (7013, 8385, 8455, 9090, 9445, 11690, 15898' ) 26 concretions have been drilled so far for a total footage of 147’ (1.6% of the lateral section). Total footage drilled in NB sands = 6770', footage out of NB Sand = 2165';Distance to WP09= 24.66' (24.66' High / 0.48' Left);Daily fluid to G&I 1254 bbls total = 11775 bbls Daily water from G pad lagoon 1560 bbls total = 11700 bbls Daily fluid lost to formation 42 bbls, total = 42 bbls Fluid lost on surface hole = 55 bbls Daily metal 5 lbs. Total= 17 lbs 8/27/2020 Cont to drill 8 1/2" Lateral F/16421' to 16,722' (301' total, 100fph AROP). WOB 10-20K, 515 gpm, 2585 psi, 140 rpm, 22Kft-lbs tq, 12.26 ppg ECD with 9.0ppg MW. P/U 183K, SOW N/A ROT 93K. Backream full stands. MPD chokes open;C/O Swab and liner on MP#2. rotate and Recip @ GPM= 310, SPP= 1280, RPM=80, TQ= 18K;Cont to drill 8 1/2" Lateral F/16722' to 16,994' (272' total, 109fph AROP). WOB 10-20K, 515 gpm, 2585 psi, 140 rpm, 22Kft-lbs tq, 12.4 ppg ECD with 9.0ppg MW. Max gas 544U. P/U 176K, SOW N/A ROT 95K. Backream full stands. MPD chokes open;Perform SPR's MP#1 32 stks @ 537#, 48 stks @ 628#, MP#2 32 stks @ 527#, 48 stks @ 610# Dynamic loss rate = 20 bph. Observed some breathing on connections.;Pump tandem sweeps. 50 bbls each 8.7 ppg Lovis (32 FV), 8.7 ppg HiVis (380 FV). Circ S-S plus 2 x BU while rotating and reciprocating F/TD @ 16994' MD T/ 16933 MD. GPM= 500, SPP= 2550, RPM=140, TQ= 19K, ECD= 12.27, Max Gas= 281u Sweep came back 25 bbls late with 25% increase in cuttings.;Pump SAPP train (40bbls SAPP pill followed by 20 bbls Quickdril x 3) followed by 9.3 ppg Quickdril. 425 gpm, 1500 psi, 11.04 ECD, Max gas 15U, 140 rpms, 23Kft-lbs. PUW 175K, SOW N/A, ROT 100K. Obtain SPR's. Monitor well through MPD, Initial flow 48 gpm consistently decreasing to static after 34 min;BROOH from 16,944' to 15,468' at 500 gpm, 1910 psi, 140 rpms, 22.5Kft-lbs, ECD 11.32 ppg with 9.3 ppg Quickdril, Max gas 360U, PUW 170K, SOW N/A, ROTW 100K. Max pulling speed 10 fpm for XBAT sampling rate.;BROOH from 15468' to 13700' at 500 gpm, 1771 psi, 140 rpms, 21.5Kft-lbs, ECD 11.0 ppg with 9.3 ppg Quickdril, Max gas 360U, PUW 105K, SOW N/A, ROTW 100K. Max pulling speed 10 fpm for XBAT sampling rate.;Distance to WP#9 33.3', 32.95' low, 4.84' left;7 faults has been crossed so far (7013, 8385, 8455, 9090, 9445, 11690, 15898', ) 31 concretions have been drilled so far for a total footage of 162’ (1.6% of the lateral section). Total footage drilled in NB sands = 6970', footage out of NB Sand = 3061';Daily fluid to G&I 2823 bbls total = 14598 bbls Daily water from G pad lagoon 1170 bbls total = 12870 bbls Daily fluid lost to formation 45 bbls, total = 97 bbls Fluid lost on surface hole = 55 bbls Daily metal 5 lbs. Total= 22 lbs 8/28/2020 BROOH from 13,700' to 11,906' at 500 gpm, 1745 psi, 140 rpms, 22.3Kft-lbs, ECD 10.8 ppg with 9.3 ppg Quickdril, Max gas 430U, PUW 160K, SOW N/A, ROTW 101K. Max pulling speed 10 fpm for XBAT sampling rate. Dynamic loss rate 8 bph, breathing back on connections.;BROOH from 11,906' to 10,188' at 500 gpm, 1630 psi, 140 rpms, 21.5Kft-lbs, ECD 10.59 ppg with 9.3 ppg Quickdril, Max gas 50U, PUW 195K, SOW N/A, ROTW 98K. Max pulling speed 10 fpm for XBAT sampling rate. Dynamic loss rate 8 bph, breathing back on connections.;BROOH from 10,188' to 8,979' at 470 gpm, 1470 psi, 140 rpms, 21.5Kft-lbs, ECD 10.62 ppg with 9.3 ppg Quickdril, Max gas 446U, PUW 190K, SOW N/A, ROTW 100K. Dynamic loss rate 8 bph, breathing back on connections. at 10,100' adjust pump rate from 450-500 gpm and;pulling speed 2-10 fpm (10 fpm max for Xbat sampling) due to slight packoffs. Slow pulling speed at 9000' to obtain bottoms up over two stands.;Cont. to BROOH from 8,979' to 7644' at 495 gpm, 1545 psi, 140 rpms, 20.5Kft-lbs, ECD 10.5 ppg with 9.3 ppg Quickdril, Max gas 454U, PUW 220K, SOW 56K, ROTW 104K. Pulling 2-8 fpm as hole dictates with consistent slight packoffs. Breathing on connection.;Daily fluid to G&I 456 bbls total = 15,054 bbls Daily water from G pad lagoon 780 bbls total = 13,650 bbls Daily fluid lost to formation 95 bbls, total = 192bbls Fluid lost on surface hole = 55 bbls Daily metal 0 lbs. Total= 22 lbs 8/29/2020 Cont. to BROOH from 7,644' to 6,913' at 500 gpm, 1560 psi, 140 rpms, 15.5Kft-lbs, ECD 10.5 ppg with 9.3 ppg Quickdril, Max gas 758U, PUW 186K, SOW 69K, ROTW 140K. Pulling 2-8 fpm as hole dictates with slight packoffs. Breathing on connection. Multiple stalls and packoffs at 7,003' (fault) work;through multiple times until cleared. Slow rotary to 40 rpms and pull through shoe with no issues.;Pump 40 bbls high vis spacer (on time , 10% increase) and circulate hole clean at 550 fpm, 1825 psi, 50 rpms, 12Kft-lbs, ECD 10.47 ppg, max gas 110U. PUW 165K, SOW 73K, ROTW 104K.;Service rig: grease crown sheaves, blocks and top drive. Service Iron roughneck. Check oil in TD and cradle welds . Monitor well during service, initial flow 55 gpm going static after 20 minutes.;Pull MPD RCD and install trip nipple.;POOH laying down drill pipe from 6,913' to 333', culling joints for inspection. Pump dry job after no indication of swabbing.;L/D BHA: HWDP, jars, float sub (retrieve drift on top of float), Flex collars, XBAT. Plug in and upload from tools. L/D TM, DM, ADR and Geo-Pilot. Bit grade 2-3-CT-A-I-X-BT-TD. Slight wear on ILS, ~1/16 gauge in DM sub. Clean and clear rig floor. Static loss rate 3.7 bph.;Rig up to run casing. Bring 205 centralizers and stop rings to rig floor. Load top row of pipeshed, bring in screens. Flag joints for screens. R/U Weatherford handling equipment and power tongs. Verify pipe count.;RIH with 4.5", 13.5#, L-80 625W lower completion as per tally to 5900'. PUW 93K, SOW 62K. TQ connections to 9600 ft-lb. Calc displacement 24.7 bbbls, actual displacment 14.1 bbls.;Daily fluid to G&I 342bbls total = 15,396 bbls Daily water from G pad lagoon 130 bbls total = 13,780 bbls Daily fluid lost to formation 70 bbls, total = 262bbls Fluid lost on surface hole = 55 bbls Daily metal 0 lbs. Total= 22 lbs 8/30/2020 Cont. to RIH with 4-1/2", 13.5#, L-80, 625W liner from 5900' to 9122' as per tally. Install centralizers on every joint. TQ connections to 9600 ft-lbs. C/O elevators and M/U SLZXP liner top hanger. R/D Weatherford. PUW 119K, SOW 55K.;RIH with 4.5" liner on drill pipe out of derrick from 9122' to 11,210'. RIH with 4.5" liner on HWDP from 11,210' to 11,660', picking up, drifting (2.75"), and single in hole. Calc displacement 18 bbls, actual 15 bbls.;Continue to RIH with 4.5" liner; pick up, drift (2.75" OD) and single in the hole with HWDP from 11,660' to 15884.97'. PUW 265K, SOW 110K.;Pump string volume at 3 bpm to ensure clear. Drop 29/32" ball and pump down at 3 bpm, 380 psi slowing to 1.5 bph with 20 bbls to go. Ball landed on seat 100 strokes early. Pressure up to 3000 psi, with indication of packer set at 2675 psi. Hold pressure for 5 minutes. Slack off to 165K.;Continue pressuring up to 4674 psi to neutralize pusher tool and shear ball seat - good indication. Slack off to 130K, pick up to 260K, liner running tool did not release. Attempt multiple times. Test SLZXP packer to 1500 psi for 10 minutes - good. Attempt to left hand release from liner top.;Trap 8K torque in string and work down, no success. Trap 10K down, work torque down until good indication of screws shearing. Pick up and confirm tool is released; PUW 235K.;PT SLZXP liner top packer to 1500 psi for 10 minutes - good.;Pick up 8' to unsting pack off. L/D joint. Break circulation 4 bpm and slowly pull liner running tool above liner top. CBU at 420 gpm, 1160 psi. Max gas 300 psi. Monitor well, slight loss.;POOH laying down drill pipe/HWDP from 6757' to 6202'; pull three joints, no indication of swabbing. Pump dry job, blow down top drive, kill and choke line. PUW 225K, SOW 135K.;Cont. POOH laying down HWDP from 6202' to 5426'. PUW 220K, SOW 132K.;Service rig: grease blocks, top drive, spinners, iron roughneck, and drawworks. check TD oil and cradle welds. Static loss rate 3 bph.;Cont. POOH laying down HWDP/DP from 5426' to 1070'. PUW 63K, SOW 62K. Calc displacement 110 bbls, Act. 128 bbls.;Daily fluid to G&I 0 bbls total = 15,396 bbls Daily water from G pad lagoon 0 bbls total = 13,780 bbls Daily fluid lost to formation 38 bbls, total = 300bbls Fluid lost on surface hole = 55 bbls Daily metal 0 lbs. Total= 22 lbs Activity Date Ops Summary 8/31/2020 Cont. to POOH laying down drill pipe from 2098', L/D liner running tool; observed circulation sub and rupture disc both sheared. Observed collet and left hand released both sheared. Calc displacement 18 bbls, actual 21 bbls.,M/U 3.5" stinger with 8.4" No-Go. RIH on elevators to 6760'MD. Kelly up and tag no go on depth at 6775'. PUW 153K, SOW 82K. Break circulation and pump 550 gpm, 660 psi, slowly pulling out of liner top. Circulate bottoms up.,Circulate bottoms up at 6774'; 550 gpm, 645 psi. Max gas 51U. PUW 153K, SOW 82K.,Pump dry job with corrosion inhibitor. B/D top drive. POOH laying down drill pipe from 6774' to 349', culling out joints for cat 5 inspecion.,RIH with excess drill pipe from derrick from 349' to 1,865'. PUW 73K, SOW 65K.,Cut and slip 87' of drill line. Check drawworks brakes - good. Static loss rate 1.2 bph.,Service rig: grease/inspect crown, blocks, top drive, iron roughneck.,Discuss Near Miss with rig crews. Hazard hunt: focus on overhead hazards with and emphasize on one sided welds/fatigued welds.,Pump dry job. POOH laying down drill pipe from 1865' to 1800', culling out joints for Cat 5 inspection.,Oncoming crew perform Hazard hunt: focus on overhead hazards with and emphasize on one sided welds/fatigued welds. Discussed near miss during pre-tour meeting.,POOH laying down drill pipe from 180 0' to surface, cull pipe as needed for cat 5 inspection. Calculated hole fill 16 bbls, actual 19 bbls.,Pull wear bushing: drain stack and BOLDS. L/D wear ring. Dummy run tubing hanger, mark landing joint.,Rig up to run 3-1/2" upper completion. Bring 110 cannon clamps to rig floor. Bring up gauge wire and spooler unit. Bring up Weatherford handling equipment, rig up power tongs. Verify pipe count in shed and tally.,Daily fluid to G&I 0 bbls total = 15,396 bbls Daily water from G pad lagoon 0 bbls total = 13,780 bbls Daily fluid lost to formation 50 bbls, total = 350 bbls Fluid lost on surface hole = 55 bbls Daily metal 0 lbs. Total= 22 lbs 9/1/2020 PJSM, P/U M/U 7"x 3 1/2" Bullet Seal Assy. TIH P/U 3 1/2", 9.3#, Eue 8rd tubing to 4113' MD, M/U XN Nipple and Gauge Mandrel as per Tally, install 1/4" Gauge wire to Mandrel. Run Cannon clamps on 1st 10 jts after mandrel then every other Jt as per tally. PUW 62k, SOW 50k,Continue TIH P/U 3 1/2", 9.3#, Eue 8rd tubing from 4113' . Tag TOL with No-Go at 6780.5', mule shoe @ 6790'.,Space out seal assy with 24.58' of pup joints,. Ran total of 214 jts 3.5" tbg. M/U Tbg Hgr and Landing Jt. Teminate I-Wire. Land out tbg hgr and verify space out. PUW 80k, SOW 55k Total 103 ea CC ran.,P/U 4.5' to clear wellhead w/ hanger. Close annular w/ 550 psi. PSI up to 500 psi on IA (seals engaged and holding psi). Bleed down to 250 psi and strip up 6' to establish communication between tbg/IA via 1" ports on bullet seal assy.,PJSM R/U Reverse Circ. 321 bbls 9.3 ppg Corrosion Inhibited Brine at 4 bpm ICP 220 PSI FCP 420 PSI. Pump 188 bbls Diesel at 4 bpm, ICP 410 PSI FCP 630 PSI. Chase W/ 10 bbls H2O. Lost 15 bbls. Shut down and land Hanger W/ 45K. RILDS as per NOS. Shoe Depth 6,786.95' MD. 3.05' off NoGo. 6.53' seals swallowed.,PJSM R/U HP hose F/ mud manifold to IA. R/U test Equip. Flood lines. MIT 9.625" X 3.5" IA to 2,500 PSI for 30 min, good. Pump 5.3 bbls, bled 5.1 bbls. Back out landing joint. P/U Tee Bar and set BPV as per NOS.,PJSM M/U Johnny Wacker flush Stack and surface lines W/ hot soapy H2O. Swap to corrosion inhibited H2O and Cont. flushing all lines. Blow down all lines. Clean out flow box and drain Stack. SIMOPS Unload 5" HWDP F/ Pipe Shed. Cont Grinding and painting tires.,PJSM Remove Upper and Lower Pipe Rams. Clean out cavities. Grease and LPS all components. Remove MPD hard lines. Remove Koomey, Choke and Kill lines. SIMOPS offload fluid in pits. Remove cap F/ De Gasser flush and clean. Pump corrosion inhibited pill through all charge pumps and pit lines. Cont grinding & painting tires. Soak Derrick W/ WR-6 soap.,Daily fluid to G&I 114 bbls total = 15,510 bbls Daily water from G pad lagoon 130 bbls total = 13,910 bbls Daily fluid lost to formation 32 bbls, total = 382 bbls Fluid lost on surface hole = 55 bbls Daily metal 0 lbs. Total= 22 lbs 9/2/2020 PJSM Remove Kill and Choke HCR valves. Remove drip pan, riser and install Beyond test cap. R/U lifting slings F/ TD to RCD, unbolt and remove RCD. Rotate BOP W/ TD 90° and set on pedestal. Remove spacer spool and DSA from well head. Prep cellar for N/U Tree. SIMOPS Cont press washing pits. Cont painting and grinding tires.,PJSM P/U and set Tree on well head as per NOS rep. Repair Sweeney wrench and complete torquing bolts. SIMOPS Cont cleaning Derrick and pits. Bring Jeep's F/ H Pad.,PJSM Centrilift perform Tec wire final test. Test Tubing Hanger void 500 PSI 5 min, 5,000 PSI 10 min, good. Test Tree 150/2,500 PSI 5 min, good. Pull CTS Plug.,PJSM Break all BOPE flange bolts. Remove annular lifting ring. Remove 1502 companion flange on well head and install blank flange. Clean drip pan. Press wash TD. Press wash and clean cutting box. Check tire press for rig move. Clean and clear around pad for rig move. Painting and grinding on tires. Prep pad for rig move.,Rig Released @ 06:00 hrs,Daily fluid to G&I 870 bbls total = 16,380 bbls Daily water from G pad lagoon 130 bbls total = 14,040 bbls Total lost on production = 382 bbls Fluid lost on surface hole = 55 bbls Daily metal 0 lbs. Total= 22 lbs 50-029-23686-00-00API #: Well Name: Field: MP I-39 Milne Point Hilcorp Energy Company Composite Report 8/14/2020Spud Date: TD Shoe Depth: PBTD: No. Jts. Returned RKB RKB to BHF RKB to THF Jts. 2 1 110 61 X Yes No X Yes No 50 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?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg) Rate (bpm): Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp:X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 1.17 8/20/2020 27 Spud Mud Type I/II 629 2.35 Class G 408 1.16 4.8 2,429.52 Casing 9 5/8 47.0 L-80 TXP Tenaris 2,394.28 2,429.52 35.24 2,451.81 2,448.98 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 19.46 2,448.98 20.62 2,472.43 2,451.81 ES Cementer 10 3/4 40.0 L-80 TXP BTC HES 2.83 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 6,839.35 Casing 9 5/8 40.0 L-80 TXP Tenaris 4,366.92 6,839.35 2,472.43 6,880.07 6,840.74 Baffle Adapter 10 3/4 40.0 L-80 TXP HES 1.39 6,840.74 1.29 6,881.36 6,880.07 Casing 9 5/8 40.0 L-80 TXP Tenaris 39.33 Float Collar 10 3/4 40.0 L-80 BTC Innovex (2) on jnt 1, (1) every joint to 5968', (1) every other joint to 3268', (1) every joint from 2673' to 2106' (5 below, 10 above ES Cementer), (1) every third joint to 157'. Casing 9 5/8 40.0 L-80 TXP Tenaris 80.05 6,961.41 6,881.36 www.wellez.net WellEz Information Management LLC ver_04818br 5208.4Water 4 Ftg. Returned 712.48 Ftg. Cut Jt.29.75 Ftg. Balance No. Jts. Delivered 193 No. Jts. Run 175 18 Length Measurements W/O Threads Ftg. Delivered 7,632.28 Ftg. Run 6,890.05 26.65 RKB to CHF Type of Shoe:Bullnose Casing Crew:Weatherford 12 263 Water ES Cementer Closure OK 6208.4 56 ArcticCem Type Class G 269 Tuned Spacer 700 2.91 Stage Collar @ 55 Bump press 100 251 6,963.006,973.00 CEMENTING REPORT Csg Wt. On Slips: Spud Mud 11:22 8/20/2020 2,449 2449 15.8 84 Bump press Returns Bump Plug? Yes 4 9.5 3 170/159.7 506.5/492.8 1270 6 Rig/HESFIRST STAGE10Tuned Spacer 58 15.8 500 9.4 3 1800 10 10.7 364 5.5 98 640 Bump Plug? Csg Wt. On Hook:255,000 Type Float Collar:Conventional No. Hrs to Run:17.5 9 5/8 47.0 L-80 TXP Tenaris BTC Innovex 1.59 6,963.00 6,961.41 9.47 35.24 25.77 Setting Depths Component Size Wt. Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP I-39 Date Run 19-Aug-20 CASING RECORD County State Supv.S Barber/ O Amend/ M Igtanloc 6,880.00 Floats Held 422.27 767 257 510 Spud Mud Rotate Csg Recip Csg Ft. Min. PPG9.5 Shoe @ 6963 FC @ Top of Liner #N/A SECOND STAGERig 19:35 Returns 382 469.7 22.9 Casing (Or Liner) Detail Shoe Cut Joint 10 3/4 40.0 L-80 69 2,449 Returns ! " #!$% &%'(' )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - * 1 * ) 2* * 0!)1234 5 + 0!)12+ ,+,+ 5 - +3,+- 6'7 8/ 88 - - / "* "* 3/* 0 ./* 435$- 405$ # 1 " * ! '('' '('' & ''! 7*7(' **0 77!(!9 (&'-."3* '(*' 1':)&;00(&9&+ 07!: 7;7!(9&!/ - 678 9" /. 6+8 / 678 ! "0 / < 9=01=)')' 0*(9& 9'(9& *1 17(1''''''' .*, * "0* / ! 0(' - , * .9 6+,8 6 8 405$ 6 8 678 435$- 6 8 +:.*)&(&* 07('''('''('')&(&* 9 6 8 / +0 6- 8 + 6 8 9=)!=)')' >? /!'. 8 '&*? @ +A -3@B ?C>?/!'.090(&& &90(7* !? 2 !5 '9='&=)')' >/.< ).. 8 '0 B@< D" . 81''(!* & 991()' !/.< ).. 82052'9=01=)')' >/.< ).. 8 '0 B@< D" . 8& 991()' 0& !))(1* !/.< ).. 82)52'9=)7=)')' 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 )&(&* '('' '('' )&(&* '('' '('' (&' & ''! 7*7(' **0 77!(!9 '('' '('' +3<+3 090(&& '()& )!!( 9 090(&& '(01 '( 00)0(70 & ''! 7*7()' **0 77!(&1 '(01 '('! >? /!'. 8205 )7 ()! 0()7 ) (*) )7 ()9 '(19 '(9)09 (' & ''! 7*7(9' **0 77!(0* 0(&7 '(** >? /!'. 8205 '1()' )( 9 )9(& '1(0& )(71 0(! )7&(!0 & ''! 7*&(79 **0 779('7 0(9' 0(! >? /!'. 8205 &9(7& (1 )(*0 &9( *( ) (*0 '9('9 & ''! 7*!( **0 77&(7 )() 7( 0 >? /!'. 8205 7 0(!' *(01 )(9& 7 0(*9 !(&! *(11 10( & ''! 7& (&9 **0 777(0* )()1 9('0 >? /!'. 8205 7!7(1' 1()9 0(0' 7!7('0 0*(1' 9(!97 (1& & ''! 7&!(&& **0 77'(9! ( 1 0 ('& >? /!'. 8205 **&(** 0'(&) '(7' ***('! )7('! 0 (&!7!7(97 & ''! 719(') **0 7 &(0 *(7' )'('& >? /!'. 8205 &0!()' 0)(90 )*(!! &0&(77 7(9& )'(7 **&(0! & ''! 799(1* **0 7)!( ) (11 )9(9! >? /!'. 8205 &90(7* 0)(!' )0(*! &11(0 7&(' )9(&'&0&(99 & ''! 7!!(9& **0 7)0('& 0(*9 1(17 >? /!'. 8205 1''(!* 0)(17 )0(*' &!&(07 7!(7) 0( '& *(9! & ''! *' () **0 709( * '(9 7'( 9 >/.< ).. 82)5 1&7(11 07(1) 0!(!& 1*9(0 &0(0 7'(9!&!1(99 & ''! *07(91 **0 7'9(&1 (0* 7!(7) >/.< ).. 82)5 )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 9)&(97 01(*0 0*()' 901(1& 1 (9' *)(**1*1(*0 & ''! *)1(7& **0 !&(! 7(!1 *9(!' >/.< ).. 82)5 9!'(*1 )'(*& 0'('9 919('0 91(90 &1(91901(1& & ''! *70( & **0 90(*0 *(7* &9(19 >/.< ).. 82)5 !**( & ) (&1 ' ()) ! 9(' 0')()1 91(7&911(19 & ''! ***(&9 **0 &0(9) &() 19('1 >/.< ).. 82)5 0 '09()* )*(1 )!!('' !!*(01 00*(90 0'!(!1! 7(!) & ''! *&!('& **0 !() 7( 0 9*(1& >/.< ).. 82)5 0 '9)() )*(1' )!1(0& 0 '*)(90 0)9(91 0 7(7&!!)(*& & ''! *90(!& **0 07(&* 0()* !)(*0 >/.< ).. 82)5 0 07*( 1 )1(&& )!7(7& 0 0'!() 070(0! 0*!(!90 '79(!9 & ''! *!7(0' **0 )9!('7 (&* !9()! >/.< ).. 82)5 0 )'!(' '(!7 )!0(! 0 0&7(17 0* (7) 099(&)0 0'7(7! & ''! &'&(0 **0 )&'( ) *(*0 0' () >/.< ).. 82)5 0 )1)(77 7() )99(1' 0 )09(01 0&*() ))'(&*0 0*1(!) & ''! &01(1) **0 ))9()) *(91 0'&(!* >/.< ).. 82)5 0 *()' 1('* )9*(&* 0 )&!(01 01&('' )**(*!0 )'9(!) & ''! &)9()7 **0 0! ()0 *( 0 0'9(!7 >/.< ).. 82)5 0 !!(** !(! )9 ('* 0 0!(*7 09*(9! )!7( 90 )*!()! & ''! & 1(91 **0 0*7( * *(0 0'!(0* >/.< ).. 82)5 0 7& (91 !(!& )90(7! 0 &9(9* 0!7(&1 7(1 0 '9(&' & ''! &7&( 1 **0 00 (!* 0(*& 0'1(!0 >/.< ).. 82)5 0 *)1(*0 7)(') )9'('* 0 70&(99 )')(7& 1*(170 *&(& & ''! &* (91 **0 '1)(9! (*& 0'*(*7 >/.< ).. 82)5 0 *!'(!0 77(*' )1!('1 0 7& ('* )'!(&& 709(*90 7')(9' & ''! &&'(19 **0 ' '('' 7('* 0')(01 >/.< ).. 82)5 0 &*7(&1 7*(!1 )11(11 0 *'1(!* )0&()! 7& ( &0 771(1' & ''! &&1('! **' !9*(09 )(1) !1(1& >/.< ).. 82)5 0 10&(* 7!()0 )1&(79 0 *7!(&1 ))0(!7 *'9(&10 79!(7) & ''! &1)(7 **' ! !(97 *(7& !)()9 >/.< ).. 82)5 0 190(99 * (09 )1&( 9 0 *!'(&0 ))1(&7 **!()10 * '( & & ''! &11(19 **' 99!()0 &('9 9*(*9 >/.< ).. 82)5 0 97*(&& **(01 )1&(!' 0 &)1(!7 ) (&) &0'(& 0 *&1(&! & ''! &9 (70 **' 9 1(90 (0! 19(!* >/.< ).. 82)5 0 !'1()! *9('! )1&(1' 0 &&0(97 ) !(10 &&0(1 0 &'0(*! & ''! &9!(0* **' 19&(&1 7(1* 1)(*' >/.< ).. 82)5 0 !1 () &'(1 )1&(0! 0 &!*( ! )7&('9 109(0 0 & *(07 & ''! &!*(0 **' 1 '() 7('& &*('7 >/.< ).. 82)5 ) ' &( ! &0(*' )1&(& 0 1)*(!' )*)()* 11 ('!0 &&*(&* & ''! 1''(!) **' &1*()7 0( & *1(1 >/.< ).. 82)5 ) 0''(0* &0(!) )11(0& 0 1*&(0) )*9(!! 9)9(9 0 &!*(91 & ''! 1'1()9 **' &0!(71 '(!9 *'(1! >/.< ).. 82)5 ) 0& (!* &'( 0 )1*(9! 0 19&(!7 )&*( * 997( 0 1)&(&! & ''! 10 ()7 **' *& (! ('1 7 (* >/.< ).. 82)5 ) ))1(*! *!( 1 )1*(*0 0 909(!0 )1'(90 ! !('90 1*9(&& & ''! 109( **' *'!(0* 0(*& *(*! >/.< ).. 82)5 ) )!0(79 *9(7! )1*(&! 0 9*0(99 )1&(0* !! (*70 1!0(& & ''! 1) ( ' **' 7*7(&& 0(7' )1(*! >/.< ).. 82)5 ) **('! *!(11 )1*('7 0 997(*) )90()& 0 '71(!'0 9)7()1 & ''! 1)9(') **' 7''()1 )()' 0!( ! >/.< ).. 82)5 ) 709(!! &'('' )17(01 0 !0&(*9 )9*(&! 0 0')(!!0 9*&( & ''! 1 )('9 **' 7*(0* 0() 0'( 1 >/.< ).. 82)5 ) 79)(*' &'( ! )1*(0! 0 !79(0* )!'(0! 0 0*1(!)0 991(!' & ''! 1 &()' **' )!'()' 0(*) 0(77 >/.< ).. 82)5 ) *7&()7 &'('! )1*()) 0 !1!(1! )!*()0 0 )0 (')0 !0!(*7 & ''! 17'(97 **' ) *('1 '(71 1(') >/.< ).. 82)5 ) &'&(97 &0() )1&('9 ) ''!(79 ''(70 0 )&*(*!0 !7!() & ''! 17*(&9 **' 09)(71 )()* 07(&9 >/.< ).. 82)5 ) &1 ( 7 *!(!* )1*(*9 ) '7)(07 '&( ' 0 ) ())0 !90(9! & ''! 1*0(0& **' 0)7(90 )(' ))(!) >/.< ).. 82)5 ) 1 &(&7 *!(19 )1&(70 ) '1 (!) 0)(') 0 11(&&) '0 (&1 & ''! 1*&(*' **' '1'( 0(01 '(*7 >/.< ).. 82)5 ) 9''( 7 &'(! )11(&9 ) 0'*(7) 09(90 0 7 )(&') '7*(01 & ''! 1&)(!) **' '0*( * )(*' 1()7 >/.< ).. 82)5 ) 9& (1& &0(9) )19(*1 ) 0 *(90 )&(&9 0 791(10) '1*(*& & ''! 11'(70 *7! !&'(0! 0(91 7)(!7 >/.< ).. 82)5 ) !)1('7 &)(' )1*(0! ) 0&*(&' ( & 0 *7 (0 ) 0'*( * & ''! 11&(10 *7! !'7(1 7(1) 7!(9& >/.< ).. 82)5 ) !!'(* &0(1' )1)('' ) 0!*(*7 &(99 0 *!!('') 0 *()! & ''! 11!(97 *7! 979(9* 7(7& *!(!& >/.< ).. 82)5 '*7(*) &0( ) )1)()* ) ))&('& 9(!& 0 &**()') 0&*(90 & ''! 190(* *7! 1!)(&7 '(&! 10(*7 >/.< ).. 82)5 001(1' &'(9' )10(&* ) )*&(&7 7'(97 0 10'(7&) 0!&( ! & ''! 19 (' *7! 1 1( 1 0(01 9 ('9 >/.< ).. 82)5 01!(9* &'(9' )1'(9& ) )9&(!& 7)(' 0 1&7(1') ))&(10 & ''! 19 (9* *7! &9 (0 0(00 !*('* >/.< ).. 82)5 )7*(09 &'(1' )10(70 ) 09(99 7 (0& 0 9)0(&!) )*9(& & ''! 197(*9 *7! &)&(0* '(1* 0'1(17 >/.< ).. 82)5 '9(9' &'( ) )10(&9 ) *'()' 77(&* 0 911('7) )9!(!* & ''! 19*(&! *7! *1'(19 '(1' 00!(&9 >/.< ).. 82)5 )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 1)(77 &'(01 )10(11 ) 90(19 7&( ) 0 ! )()1) )0(* & ''! 19&(!9 *7! *0*(*& '()1 0 0(7 >/.< ).. 82)5 7 7(*1 &'(*0 )1 (0& ) 70)(* 79(&7 0 !9&()0) *)()9 & ''! 199(! *7! 7&0(&0 )(') 07)()) >/.< ).. 82)5 7!!(&* &'(0& )1)(1 ) 777(17 *0(** ) '7)(&9) 97(7! & ''! 1!0(77 *7! 7'*(0) '(1! 0* ('1 >/.< ).. 82)5 *& ()) &'(9! )1)(70 ) 71&(') *7(' ) '!1(!1) 70*(11 & ''! 1! (*7 *7! 7!(9) 0() 0&7(' >/.< ).. 82)5 &)1()& &'(' )1 ()' ) *'1(*! *&(1* ) 0* (&)) 771( 7 & ''! 1!*(99 *7! )!7(0& 0(1) 017(9* >/.< ).. 82)5 &!'(*) *!(17 )1 ('* ) * !( *!(1 ) )'9()&) 71!('9 & ''! 1!9(7! *7! ) !(*0 '(*' 09*(09 >/.< ).. 82)5 1*7(!1 &)(07 )1 (77 ) *1'(& &)(! ) )&7(*') *0'( 9 & ''! 9'0()! *7! 09 ()* (1& 0!*(&! >/.< ).. 82)5 909(71 &0()! )17(0 ) &''(1) &&(&) ) )'()!) *7'(71 & ''! 9'7(&' *7! 0)1(77 0(&* )'*(&' >/.< ).. 82)5 99)(' &'(0* )1 ( 9 ) & 0(90 1'()* ) 1*(&0) *10(*& & ''! 9'1(9* *7! '1)(0' )('1 )0*(7& >/.< ).. 82)5 !7*(9 &'(90 )1)(9& ) && ()7 1 ()1 ) 7 0('*) &')(!! & ''! 90'(79 *7! '0&(&* 0()* ))*(!7 >/.< ).. 82)5 7 ''9(9& &'(01 )1 (1' ) &!7()! 1&(70 ) 79*(90) & 7('7 & ''! 90 ()7 *79 !&0(99 0(*7 ) &(0* >/.< ).. 82)5 7 '1)( ! &'(9! )1&(7& ) 1)*(** 90( 0 ) *7'(9!) &&*( ' & ''! 901(1& *79 !'&(1& (!* )77(1) >/.< ).. 82)5 7 0 *(1& &)(0* )19(7 ) 1**(11 99(* ) *!&(0)) &!*(*) & ''! 9)7(&' *79 9*0(7! ( 9 )*0('1 >/.< ).. 82)5 7 0!!(!' &)(7& )90(01 ) 19*(*9 !9()' ) &*)('1) 1)*( & ''! 9 (99 *79 1!*(79 (90 )**() >/.< ).. 82)5 7 )& (*& &0(9* )9)(!9 ) 90*( ) 7'!(!1 ) 1'1(00) 1**('1 & ''! 97*()9 *79 17'( & )(&! )*1(0) >/.< ).. 82)5 7 )1(* &'(17 )9)(01 ) 97&('* 7))(0! ) 1&0(91) 19*(9' & ''! 9*1(00 *79 &9*(* )('& )*9(*0 >/.< ).. 82)5 7 !0('0 &'(90 )9 ('1 ) 911('7 7 7()! ) 90*(! ) 90&(1! & ''! 9&9(97 *79 & 0( ! 0()7 )*!(9* >/.< ).. 82)5 7 7*7(9) &'(91 )9)(97 ) !'9(0 77&(19 ) 91'()7) 971(99 & ''! 99'(!& *79 *11('0 '( )&'(9& >/.< ).. 82)5 7 *09(&7 &0(0* )9 (7! ) ! !('& 7*!(*' ) !)7(&') 919(90 & ''! 9! ( ' *79 *))(*1 '(!! )&0(&9 >/.< ).. 82)5 7 *9)(09 &0(') )9 ('0 ) !&!(19 71)()7 ) !19(1 ) !'!(* & ''! !'*(&1 *79 7&9( * '(&! )&)(7' >/.< ).. 82)5 7 &7*(9) *!(!* )9 ()' ''0(07 797(9' ' )(&1) !7'(9! & ''! !01(9* *79 707( 0(1' )& ()1 >/.< ).. 82)5 7 1'!( & *!(1 )9 (*& ' ('& 7!1(*0 '9&(0)) !1)(90 & ''! ! '()' *79 &'(9' '(&' )& (9& >/.< ).. 82)5 7 11 (0& &'(77 )9 (97 '&7(99 *0'(&0 0 !(97 ''7(& & ''! !7)(!) *79 '&(!! 0(09 )&7(0* >/.< ).. 82)5 7 9 1(' *!(97 )97(*7 '!&(&9 *)7(0! 0! (*7 ' &(7 & ''! !*&(0 *79 )* ()0 0( 7 )& (!1 >/.< ).. 82)5 7 9!!(97 &)(79 )97(79 0)&(!1 * 1(!1 )7&(9' '&&(1) & ''! !&!(*7 *79 0!!(9& 7()' )& (79 >/.< ).. 82)5 7 !&7(') &)(71 )97(1' 0*&(& **)( 0 '0(99 '!&( 9 & ''! !9 (*' *79 077(&9 '( ' )&)(9! >/.< ).. 82)5 * ')&(0& &)(79 )97(9) 09*( * *&&( * **(01 0)*(0' & ''! !!1(01 *79 '!0( 0 '(01 )&)(0& >/.< ).. 82)5 * '!0(00 &)(!1 )97(1 )0*(00 *90('1 70'(!! 0*7(9& & '0' '00(*' *79 ' *( ! '(1& )&0( 9 >/.< ).. 82)5 * 0*7(*& & (09 )9&(9! )7 (9* *!&(79 7&*(7) 09 (&' & '0' ')&(*7 *71 !9'(9& ('* )*!(&' >/.< ).. 82)5 * )09(01 &)(!0 )99(9) )1)(&9 &0 (91 *0!( 9 )0)(7 & '0' '7 (*7 *71 !)&(1! )(17 )**(19 >/.< ).. 82)5 * )90(1) &)(7' )99(9) '0(99 & )('9 *1)(9) )70(& & '0' '&0( 9 *71 91 ()7 '(9' )*0('7 >/.< ).. 82)5 * 77(&& &)(79 )!'( 0('' &*'(11 &)*( ! )1'(1* & '0' '1!(10 *71 9)'(*7 )(0 )7*(&) >/.< ).. 82)5 * 7'1(') & (!* )! ( ! *!(0' &10(*' &11('7 )!9(9* & '0' 0''('! *71 1&9(1* 7(!1 ) 9('' >/.< ).. 82)5 * 7& (17 &7(91 )!&()& 9 (&0 &!)(!9 1) (7& ) ( & & '0' 0)0()7 *71 1))(0! 7(97 ))9( ! >/.< ).. 82)5 * * *(&) &7(9! ''(&0 707(0 1) (!& 19'(&1 * (99 & '0' 0*0(9) *71 &&7(11 *(7! )0)(01 >/.< ).. 82)5 * *!9(! &7(&' ' (7) 770(0* 1*7( 0 9)!()0 9'(!' & '0' 090(97 *71 &0&(' 7('7 0!7(71 >/.< ).. 82)5 * &&)(17 &*(0' '&(90 7&9()1 191(*7 91&(7* 7'9(') & '0' )07(1 *71 *&9(*1 7(91 01 (&& >/.< ).. 82)5 * 1)1()0 &&(!' 00('1 7!7(*' 9)7(** !))() 7 7()* & '0' )*0(7 *71 *))(* &(&& 079(90 >/.< ).. 82)5 * 1!'(** &9(01 07(9' *09(10 9&7(7 !&*('1 7*9(7& & '0' )!0('' *71 71!(7 *(9' 0)'(7! >/.< ).. 82)5 * 9*7( &1(0' 01(* *7)(!9 !'&(!& 7 ''*(!) 79)(1 & '0' ()* *71 7 9()! 7( ' 9!(0' >/.< ).. 82)5 )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 * !01()* &7(&! 0!(&' *&9(&9 !*'('0 7 '7 (! *'9(7 & '0' 1&(' *71 !!(!! 7(91 *&(*) >/.< ).. 82)5 * !9'(97 &*(!' ) (*& *!*()& !!*()& 7 '1!(90 * *('0 & '0' 7)0(' *71 & (9' *(!1 )0( ' >/.< ).. 82)5 & '77(*9 &9( 1 )1(*9 &)'('7 0 '7 (1' 7 00)(!! **!(1! & '0' 7&!() *71 '()! &(!! 01(&9 >/.< ).. 82)5 & 0'9(1! &9(10 )!(! &7 (* 0 '!7(1! 7 07 (!9 *9 ()9 & '0' *)'(0' *71 )!9(!* (77 *!(1* >/.< ).. 82)5 & 01)('* &!(!& 0()0 &&*(9& 0 07&( 7 01 ('* &'*(&0 & '0' *10(77 *71 )&!(*) )(17 0')(1 >/.< ).. 82)5 & ) *(!& 1)(1& 7(0& &9&()! 0 )''(0 7 )''(9) &)&('7 & '0' &)*('7 *71 )70( ! &(09 079()0 >/.< ).. 82)5 & )!!(*! 1&(9! 9( 0 1')(!& 0 )*&( ) 7 ))*(*7 &7)(10 & '0' &90('* *71 )0&()! !('7 0!&(1& >/.< ).. 82)5 & & (9' 19('7 70(91 10&(!' 0 0*()* 7 )7&(91 &*&(&* & '0' 1 !(9) *71 0!7(** *(1' )79(11 >/.< ).. 82)5 & 7)&(97 1&(7* 7 ()& 1 '(9) 0 1 (!' 7 )&*( ' &1'(*1 & '0' 1!9( 7 *71 01*(1) ( ) '0()) >/.< ).. 82)5 & 7!'( 11(1! 7*(97 177(!9 0 7 (** 7 )90(19 &97(1 & '0' 9*1(91 *71 0*9(9 7(7! **(00 >/.< ).. 82)5 & **7(&) 1!(91 79(!9 1*1(7 0 7!*('! 7 )!*(*) &!1(09 & '0' !0!( 0 *71 077(&& *(19 700(*' >/.< ).. 82)5 & &01(*& 9)( * *)( 1 1&1(0& 0 **&(77 7 '*(*! 1'&(!0 & '0' !9'(*9 *71 0 7(01 &(&) 7&9(*! >/.< ).. 82)5 & &9'(!7 9 (00 **()1 11*(09 0 &09(!7 7 0)( & 107(! & '00 '7 (' *71 0)&(!1 7(1' *)1(*! >/.< ).. 82)5 & 177(!! 9 ()9 *1(&* 19)(11 0 &9)(70 7 0&()! 1))(*) & '00 0'&(7& *71 0))(&0 (10 *99() >/.< ).. 82)5 & 9'9(1) 97(0' *!( 9 19!(19 0 17*(17 7 01(! 1)!(* & '00 0&!(11 *71 0)'(* )(!9 &7!()9 >/.< ).. 82)5 & 910(!! 9 (1! '('1 1!&(7* 0 9'9(&* 7 09() 1 &()' & '00 ) )(&1 *71 00!(9' 0()' 10'()* >/.< ).. 82)5 & 991()' 9*(') *!(!9 1!1(! 0 9) (1! 7 09()) 1 1(&9 & '00 )71(90 *71 00!(1' 9(0 1)7(!7 >/.< ).. 82)5 & !1)('* !'(!& )(1 9''(!0 0 !'9(*0 7 0&()0 17'(&& & '00 )(*7 *71 0)0(0) 1(10 9'1(&7 >/.< ).. 82 5 1 ''0('7 !0(') )( 9 9''(70 0 ! 1(71 7 07(!) 17'(0& & '00 &0(*' *71 0))()) 0()) 9 &('7 >/.< ).. 82 5 1 '&7(19 !0(0* )()& 1!!()' ) ''0(0* 7 0)( 7 1 9(!* & '00 7)*(0! *71 0)7( & '()9 9!9(7* >/.< ).. 82 5 1 0)&(*! !'(10 )(') 1!9()' ) '&)(!' 7 0'(' 1 1(!* & '00 79&(!* *71 0)&()7 '(90 !*9(!7 >/.< ).. 82 5 1 0!0(!9 99(!9 )()7 1!9( 9 ) 0)9()* 7 '1(&' 1 9(0 & '00 **)( 0 *71 0)9()) )(&1 0 '))(! >/.< ).. 82 5 1 )**(1' 99( 1 (71 1!!(9* ) 0!0(91 7 '7(7 1 !(&' & '00 &0*(!7 *71 0 '(!* )(0* 0 '9*(7 >/.< ).. 82 5 1 0!(!' 9&(& (&) 9')(&* ) )**(99 7 ''(7& 17)(7' & '00 &1!(!9 *71 0 7(71 )(1) 0 079(*' >/.< ).. 82 5 1 9 ('7 91(*' (*7 9'*(99 ) 09(9) 7 )!&(* 17*(& & '00 17)(! *71 0 1(!9 0( 9 0 )0'(*0 >/.< ).. 82 5 1 77&() 99( ' 7(9& 9'9()' ) 90(1! 7 )!0(!' 171(!* & '00 9'*(! *71 07)(01 )(77 0 )1)(17 >/.< ).. 82 5 1 *'!(!' 99(** 7(0 9'!(!* ) 77*()7 7 )9&(!0 17!(1' & '00 9&!(70 *71 07&(1) 0()0 0 *(*0 >/.< ).. 82 5 1 *1 ()* 9!(7) (!7 900('1 ) *'9(7) 7 )9)(7& 1*'(9) & '00 ! )(&0 *71 0*'(17 0(70 0 !1(9! >/.< ).. 82 5 1 & &(1& !'(*! (17 900('& ) *10(1! 7 )19()' 1*'(90 & '00 !!&('' *71 0*7(** 0(91 0 7&'(70 >/.< ).. 82 5 1 1''(& !'(!' (! 90'() ) & *(*0 7 )1 (! 17!(!9 & '0) '*!(17 *71 0*9( 9 '(*1 0 *) ()1 >/.< ).. 82 5 1 1&7('& !0(1& )(!* 9'9(1& ) &!9(90 7 )1'(0 179(*0 & '0) 0) ('& *71 0&0(1* )('& 0 *9*(&0 >/.< ).. 82 5 1 9)*(17 !0(!* )( 9 9'&(11 ) 1&'( ! 7 )&1()& 17&(*) & '0) 097(&* *71 0&7(0! '(!1 0 &7&('* >/.< ).. 82 5 1 99!()9 !)(*' 0(9) 9'7( ' ) 9) (97 7 )&7(! 177('* & '0) )79(00 *71 0&&('9 0() 0 1'9(09 >/.< ).. 82 5 1 !* (97 !)()& (7! 9'0(&) ) 999()1 7 )&0(!* 170( 1 & '0) 0)(** *71 0&9(& )(&0 0 110(7) >/.< ).. 82 5 9 '01(** !'(*! ('1 9''(' ) !*0(9& 7 )*9( ' 1 !(19 & '0) 1&(0* *71 010(9 )(1' 0 9 7('' >/.< ).. 82 5 9 '90(*1 99(!9 )(*' 9''()1 '0*(9' 7 )**(0! 17'(') & '0) 77'(00 *71 017(*' )(&1 0 9!&(1! >/.< ).. 82 5 9 07*(07 91(1* 0(&) 9')('! '1!( ' 7 )*)(!0 170(97 & '0) *' (&) *71 01&( 7 )( 9 0 !*9(!& >/.< ).. 82 5 9 )'9(&9 9*(!* '(&! 9'*(*9 07)(1 7 )*0(& 17*( & '0) *&1('* *71 011(0! (0! ) ')'(90 >/.< ).. 82 5 9 )10(** 97(1) '() 90'(&! )'*( 9 7 )*0(0 1*'(77 & '0) &)!(1' *71 011()& )('! ) '90(1 >/.< ).. 82 5 9 *(0) 9 (79 *!(*0 901() )&9(&) 7 )*0()1 1*&(!9 & '0) &!)(! *71 01&(&9 )()* ) 07 ('* >/.< ).. 82 5 )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 9 !9( ) 9 (&' *!(&! 9)7( 7 0(70 7 )*0(10 1&7('! & '0) 1**(10 *71 01*(90 '( 7 ) )' (91 >/.< ).. 82 5 9 7&0(!7 97(* '()7 9 '(!0 !7(&! 7 )*0(17 11'(&& & '0) 909(!9 *71 01*( 0(1' ) )&*()& >/.< ).. 82 5 9 *)*(&1 91(*& 0(&' 9 *( 0 7*9()* 7 )*'(1) 11*('& & '0) 99)(*7 *71 01*(!) *()0 ) )1(09 >/.< ).. 82 5 9 *9!(77 9!(*7 )(&0 9 &(!) *)0(!* 7 )79( 9 11&(&1 & '0) !7&()* *71 011(9) (7! ) 9!(*& >/.< ).. 82 5 9 &*)(!9 9!()! (77 9 1(*1 *9*(7' 7 )7*(' 111( ) & '0 ''!(1) *71 09'(1 0( & ) 7*0(!7 >/.< ).. 82 5 9 10&(&1 91(*' (&& 9 !( & &79(!7 7 )70('! 11!(00 & '0 '1 ()9 *71 097()7 )(9 ) *07(*7 >/.< ).. 82 5 9 11!(*) 9*(*) ()1 97 (09 100(*& 7 ) 1()! 19)(! & '0 0 *(!0 *71 091(*! ()0 ) *1&()0 >/.< ).. 82 5 9 97 (&0 9&()' ( 7 971(90 11*( 1 7 ) (&0 191(*& & '0 0!!(17 *71 0!'(97 0('1 ) & !(' >/.< ).. 82 5 9 !'1('7 99(!) 7(00 9*'(*0 9 9(&0 7 ))!(7! 1!'()& & '0 )& ('' *71 0!7(*) 7(7& ) 1'0( 9 >/.< ).. 82 5 9 !10()! !)('0 7(*1 97!(!! !')(&& 7 ))7(& 19!(17 & '0 )1('9 *71 0!9(!7 7(9& ) 1&7(10 >/.< ).. 82 5 ! ' 7(&) !)( ) (!0 971(&' !&*(11 7 )0!(!* 191( * & '0 !'()0 *71 )' (09 0(0* ) 9)1('1 >/.< ).. 82 5 ! '!9(71 !)(0! ( 9 97*('9 7 ')!(77 7 )0*(!' 197(9 & '0 7* (!0 *71 )'&(9' '(9* ) 99!(9 >/.< ).. 82 5 ! 0&)()9 !)(&! )(&' 97)( 1 7 '! (00 7 )0)(*1 19)(0) & '0 *01(*! *71 )'!(&9 0(7* ) !*)(70 >/.< ).. 82 5 ! ))&('1 !)(90 0( 9 9 !( 0 7 0*&(1! 7 )0'( & 11!('& & '0 *90()1 *71 )00(7& 0(!) '07(1 >/.< ).. 82 5 ! )9!(11 !)(*' 0(0* 9 &( & 7 ))'(7' 7 )'9(!* 11&(00 & '0 &77(9! *71 )0)(7) '(&0 '1&(9' >/.< ).. 82 5 ! * (77 !)(0! '(99 9 (1* 7 )97('0 7 )'1(9 11 (*' & '0 1'9(*' *71 )0 (00 '(&* 0 9(1! >/.< ).. 82 5 ! 701()* !)(& '(1! 9 0('1 7 71(1& 7 )'&(!' 11'(9) & '0 11)()7 *71 )0 (&' '(1' )''(91 >/.< ).. 82 5 ! 79'(17 !)(0! '(!& 9)9(7' 7 700(09 7 )'*(! 1&9(0* & '0 9 *(&1 *71 )07(0 '(17 )&)(&7 >/.< ).. 82 5 ! *7 (97 !)(*' 0(09 9)*(9) 7 717()) 7 )'7(1* 1&*(*1 & '0 9!9(1' *71 )07(91 '(&' )7('! >/.< ).. 82 5 ! &'1(*9 ! ()* )(*1 9))(&) 7 * 1(97 7 )')(&1 1&)( 1 & '0 !&)( *71 )0&(*) )(79 9&( >/.< ).. 82 5 ! &&1(1! ! (&) )(!) 90!('0 7 *!1(91 7 0!!(1! 1*9(1& & '07 '))( 9 *71 )09(!9 '(9* 77*()9 >/.< ).. 82 5 ! 1 7(7! ! (** (1& 907(97 7 &&7( 7 0!*(!0 1*7(*! & '07 '99(9* *71 )))(7' 0()& *0'(1' >/.< ).. 82 5 ! 1!9(1 !)(!7 7(01 900()' 7 1)9( 0 7 0!0(79 1*'(!* & '07 0*)(9& *71 ))&( ! 0(07 *1 (9* >/.< ).. 82 5 ! 9&)()7 ! ( 0 &(!9 9'1(17 7 1!0(7) 7 09*( ) 171(7! & '07 )0&('' *71 ) )(0) 7(7& & &(*9 >/.< ).. 82 5 ! !)&('7 !0(0) 1(1* 9'*()1 7 9*7(&7 7 011(0* 17*(') & '07 )1!()1 *71 ) !(9* (&7 &!!(!' >/.< ).. 82 5 ! !9!(&9 !0(') !(0! 9'7('! 7 !01(*9 7 0&1(11 17 (97 & '07 7)()& *71 )79(1! )()1 1& () >/.< ).. 82 5 0' '*)(9* 99(7! !(!7 9'7( & 7 !1!(9& 7 0*1()9 177(00 & '07 7'7(&0 *71 )*9(9* 7(09 9)&()' >/.< ).. 82 5 0' 00&(10 9&(&7 0)(7! 9'1('1 * '7)(77 7 077(91 17&(9) & '07 7&1()1 *71 )1'(9 7(! 99!(!) >/.< ).. 82 5 0' 01!( 7 9&()' 0*(70 90'(!9 * 0' (0' 7 0)!(9' 1*'(1 & '07 *)9(') *71 )9*(71 7(10 !*)(7) >/.< ).. 82 5 0' )7 ()* 91(!7 09('7 907()* * 0&7()0 7 000(77 1*7('' & '07 *9!()& *71 ' (7) 7(! 7 '0&(01 >/.< ).. 82 5 0' '&(1! 99(&0 0!( 90&(0& * ))7( 9 7 '!0('! 1**(!0 & '07 &7!(*& *71 ) ( 7 )()! 7 '1!(71 >/.< ).. 82 5 0' 10()' 91( ) 09(*' 909(7* * )9*()1 7 '1'() 1*9()' & '07 10'(*9 *71 7 (1! )( 9 7 07 (&' >/.< ).. 82 5 0' 7 7(*0 99('' 0!(79 9)0(' * 7*('9 7 '7!(&7 1&'(19 & '07 11'(* *71 & (!& 0(99 7 )'&(&0 >/.< ).. 82 5 0' 7!9(* 99()7 0!()1 9) (0 * 7'*(77 7 ')9(70 1&)(99 & '07 9 0(' *71 97(1& '(*' 7 )1'( ) >/.< ).. 82 5 0' *&)(0* 99( 1 0!(! 9)*(') * 7&*( * 7 ''1('9 1&7(11 & '07 9!0('9 *71 7'*(&9 0('& 7 (&0 >/.< ).. 82 5 0' &)*( * 91( 0 0!(*! 9)1(7' * *)7(1! !9*(1 1&1(0* & '07 !*'(&* *71 7)&(&) 0(1& 7 !&(77 >/.< ).. 82 5 0' &9!(*' 9&(*9 09(' 9 '(9) * *9*(7) !&*('9 11'(*1 & '0* '00(7 *71 77&(9* )(&9 7 7&'()1 >/.< ).. 82 5 0' 1* (*0 91(91 0&(7* 9 (!) * &7&(79 !7&(0 11 (&1 & '0* '1)(&0 *71 7&*( 9 (09 7 *)7(0' >/.< ).. 82 5 0' 90&(79 91( 9 07(&& 9 &(* * 1'1('! !)!()& 11&()9 & '0* 0 ( *71 790(9 )(!7 7 *9&(!! >/.< ).. 82 5 0' 99'() 9&()& 07(07 97'('& * 1&9(17 !0 (7 11!(90 & '0* 0!*('9 *71 7!1() 0(!7 7 &*'(&7 >/.< ).. 82 5 )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 0' !77('' 9&(99 07(70 97 (99 * 9 '(7 9!1(1 19 (& & '0* )*&(91 *71 *0)(*' 0('& 7 107()! >/.< ).. 82 5 00 ''1()* 9&(1& 07(' 971( ! * 9!0(&* 99)()) 191(07 & '0* 09(0! *71 *)1(*! '(& 7 111(7* >/.< ).. 82 5 00 '10('& 9&(9) 0 (*! 9*'(!& * !* (*) 9&1('0 1!'(10 & '0* 9'(0* *71 *7)( 1 '(&! 7 970(0& >/.< ).. 82 5 00 0 7(*! 91('1 0)(*! 9*7( 7 & '0*( 0 9*)(&7 1!7('! & '0* 77)(' *71 **&( 0 0(&) 7 !'7(*! >/.< ).. 82 5 00 0!9(0& 9&(*9 0)(*1 9*1(91 & '11()* 9 9(9) 1!1(&) & '0* *'7('1 *71 *&!(1' '(11 7 !&9('7 >/.< ).. 82 5 00 )&0(!0 91('1 0 ( 9&0(7' & 0 !()! 9)7(*& 9'0(0* & '0* *&&(0! *71 *9 (*7 0(7) * ' 0(&9 >/.< ).. 82 5 00 )*(1' 99(!) 0)(7 9& (& & )'0(7 90'( * 9' ( 9 & '0* &)9(7 *71 *!1( ) ()) * '!*(7) >/.< ).. 82 5 00 9!()) !'(0' 0)(!9 9&7(01 & )& ( ! 1!&( 9 9' (!) & '0* &!'(79 *71 &0'(9& )('* * 0*9(!) >/.< ).. 82 5 00 7* (0* 9!(!1 0 (70 9&7(0 & )*(& 190(19 9' (99 & '0* 1*)(90 *71 &)*(') '(1' * )))(97 >/.< ).. 82 5 00 *0&(*0 9!(00 07( 9 9&7(&7 & 91(07 1&&(*1 9'7( ! & '0* 907(70 *71 & !(90 )('* * )9&()' >/.< ).. 82 5 00 *9'('1 9!(79 0*() 9&*(7) & 779(*9 1*'( 9'*(01 & '0* 91*(!& *71 &**(&) 0(7& * 7!(17 >/.< ).. 82 5 00 &7 (!' 99(9' 0*(7' 9&&( 9 & *0'(07 1 (71 9'&(0 & '0* ! 1(& *71 &1)('* 0(0' * 70 (** >/.< ).. 82 5 00 1'1(*) 91(90 0*(*' 9&9()& & *10(7 10&(* 9'9('0 & '0* !!!(' *71 &99(*1 0(*& * 711(0) >/.< ).. 82 5 00 110(&1 99(0) 0*(&' 91'(*7 & & (0! &!!( * 90'()! & '0& '&'(!' *71 1'*( '(*0 * *70()0 >/.< ).. 82 5 00 9 7(!7 9!(!0 01(1! 910(& & &! (19 &90(01 900( 9 & '0& 0)0(&0 *71 1) ('9 7(71 * &'7( ! >/.< ).. 82 5 00 9!9(') 9!(1) 09(99 910(9 & 1* (&& &&0( 900(*9 & '0& 090(&) *71 17)(*' 0(1* * &&1()! >/.< ).. 82 5 00 !&0(9! 9!(!0 09(91 91)('7 & 907('! &7'(&1 900(1! & '0& )7)(0! *71 1&)(1* '( ' * 1 '(! >/.< ).. 82 5 0) ')*(&! 9!(&& 09(&* 91)()9 & 917(*' &)'(0* 90)(' & '0& ')(1 *71 19)(9* '(*) * 1!7(*0 >/.< ).. 82 5 0) '91(! 9!(&& 09(70 91)(&* & ! (*) &''( 1 90)(7' & '0& &0(91 *71 9')()) '( ! * 9*&(** >/.< ).. 82 5 0) 0*0( 9!(1! 01(1 91)(!* & !! (1! *9'(10 90)(1' & '0& 7))()1 *71 9)0(7& 0('! * !0!(1! >/.< ).. 82 5 0) )0*(9* 9!(01 01(0! 91 (*7 1 '**( *&0( * 90 ()! & '0& 79 (!7 *71 97'( ! 0()1 * !97(0! >/.< ).. 82 5 0) )1!(*7 99()7 0&()' 917(!9 1 00&( ) *7 ('& 907(1 & '0& *7*('* *71 9*9()& )(0 & '71(1! >/.< ).. 82 5 0) 77(*! 99()7 0&( & 91&(!1 1 019(1 *)7(9 90&(1) & '0& &'1(*9 *71 91&('& '()* & 00)(1& >/.< ).. 82 5 0) 7'9('9 9!('* 01(' 919(79 1 ) !(* *'&(&' 909() & '0& &&9(7! *71 9! (91 0(&& & 01&(0& >/.< ).. 82 5 0) 710( ) 9!(01 01(9' 91!(7& 1 )!!(9& 791(&1 90!()0 & '0& 1)9(!* *71 !0)( 9 0() & ) !()9 >/.< ).. 82 5 0) * *(0& 99(9' 01(11 99'(*! 1 &'(&7 7&9(01 9)'( 7 & '0& 19!(9& *71 ! 0(7* '(*9 & ')(!1 >/.< ).. 82 5 0) *!9(1) 9!() 09(&& 990(&9 1 7)0('0 779( 0 9)0(7 & '0& 9*'( * *71 !*'(!' 0(** & &&( * >/.< ).. 82 5 0) &&0(1) 91( ) 01(!9 99 (*9 1 79'(19 7)9(*) 9) ( & '0& !0'()& *71 !1'()1 ()) & 7)!(07 >/.< ).. 82 5 0) 1)*(') 9&(&7 09(79 99&(!0 1 *7'(9) 7'9(17 9)&(&& & '0& !1'(7 *71 !9!(& 0( & 7!)(09 >/.< ).. 82 5 0) 199(*! 9&( ! 09(0& 9!'(19 1 &'0('& 99(9' 9 '(* & '01 ' '(1! *79 ''!(0& '(&7 & ***(7* >/.< ).. 82 5 0) 9* (0* 9&(07 09( 7 9!7(!9 1 &&)()7 &9(&) 9 7(1 & '01 '!)(00 *79 ')9(!0 '(79 & &0!(&! >/.< ).. 82 5 0) !0&(*0 9&(*0 09(91 9!!('7 1 1))(0& 79(7* 9 9(1! & '01 0*)(0& *79 '79(&1 0(') & &9)(1) >/.< ).. 82 5 0) !9'( ' 91(! 09()* !')(07 1 19)(*& )9(01 970(9! & '01 )0)(1' *79 '&9(* )(7 & 17&() >/.< ).. 82 5 0 '7 (*! 99(!) 01(!! !' (99 1 97)(&! '9(7! 97 (& & '01 )1)(!* *79 '91(1! 0(&) & 9'!( >/.< ).. 82 5 0 0'1( ' 99(9' 0&(!! !'*(0* 1 !' (77 )9!( * 977(!' & '01 (9 *79 0'&(*0 0(*9 & 91)(!0 >/.< ).. 82 5 0 01'()& !'(&* 07(&1 !'*(7* 1 !&7('0 )1)(09 97*()' & '01 !7(*0 *79 0) ()& 7(10 & ! *(9 >/.< ).. 82 5 0 ) (7) !)(0 0&()7 !' (!) 9 ')7(9& )**( * 97 (&1 & '01 7**(71 *79 0 !(&& (7) & !!9(!* >/.< ).. 82 5 0 )!1()0 !0(07 0&(!& !')(0' 9 '9*(!1 ) 1(07 970(9* & '01 *0&(&! *79 0*1(7& 0(!) 1 '&)(&* >/.< ).. 82 5 0 &0( 1 9!(00 09()! !'0(!& 9 071(00 )01(10 970(10 & '01 *11(!& *79 01&(7& (19 1 0)&(&1 >/.< ).. 82 5 0 7)7(&& 9!(7) 09( 1 !')(11 9 )'1(0! 0!1(90 97)(*) & '01 & 9(01 *79 0!*(!7 '(*0 1 09!(19 >/.< ).. 82 5 )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 0 799(!7 9!(1! 09(&' !' ()0 9 )&9(0* 011(7 97)(!& & '01 &!!()& *79 )0*(!' '(&9 1 )* (9& >/.< ).. 82 5 0 **)(1* 99(&9 09(91 !'7('& 9 )9(*1 0*&(!7 97 (90 & '01 1*!(9) *79 ) *(!1 0(1! 1 01(77 >/.< ).. 82 5 0 &0&( ) 99(!9 )'('* !'*( & 9 99(*' 0 *(1& 97*(00 & '01 90!(99 *79 )*&(1 0(!0 1 9'(10 >/.< ).. 82 5 0 &1!(1' 9!('* )'(1& !'&(7* 9 771(9! 00 (&1 97&()' & '01 91!(7) *79 )19(70 0(0 1 77 (&! >/.< ).. 82 5 0 17 (*& 9!(!0 )0(&! !'1(' 9 *'1(70 '!'(** 97&(19 & '01 ! !(0' *79 '0(0) 0(!9 1 *'1('7 >/.< ).. 82 5 0 9'1(&0 !'(0' )0()9 !'1(') 9 *&1('0 '&1('! 97&(11 & '01 !!9(9* *79 )7(0& '(10 1 *1'(*7 >/.< ).. 82 5 0 91'()& !'(' 0!(!9 !'&(!* 9 &)*(&7 '7*(') 97&(1' & '09 '*1(& *79 7*(9 )('9 1 & )(11 >/.< ).. 82 5 0 ! 7()) 9!(9* 09(!! !'1(') 9 &9*(!7 ') (&! 97&(11 & '09 009('& *79 &&(17 0(*1 1 &!&(77 >/.< ).. 82 5 0 !!1(1) 9!(!0 09(!1 !'1(0* 9 17*(!! '' (' 97&(!' & '09 019()* *79 9&(!9 '(0' 1 1*!(1' >/.< ).. 82 5 07 '&0(1* 9!(!1 09(&) !'1()) 9 9'&(&' ) !9)(7' 97&(!1 & '09 ) !('' *79 7'1(0! '(** 1 9) (*' >/.< ).. 82 5 07 0)*(77 9!(9* 09( 9 !'1( ) 9 9&1('' ) !&)(0! 971('1 & '09 )!!(* *79 7)&(!9 '(7) 1 99&(!! >/.< ).. 82 5 07 09!(77 9!(&& 09(77 !'1(*! 9 !)1(1 ) !70(!9 971( 7 & '09 &'( 9 *79 77&(11 '( 0 1 !*'(9' >/.< ).. 82 5 07 )* (' !'(' 01(1) !'1(11 9 !99(09 ) !))()* 971(*) & '09 7)'(!& *79 7&&('9 0()1 9 '07() >/.< ).. 82 5 07 0&(* 9!(9* 01()! !'1(9 ! '79(1 ) !' (0* 971(*9 & '09 790(&* *79 797(1& '(1 9 '11(&0 >/.< ).. 82 5 07 9'(0' 9!()! 01(&* !'9( 0 ! 0'!( 1 ) 997('& 979('& & '09 *7)(70 *79 *' (7 0('* 9 070('& >/.< ).. 82 5 07 77 (1! 9!('* 01(9) !'!() ! 01'(' ) 9&7(&1 979(!9 & '09 &' (0! *79 *))(7' '(7& 9 )'7(&0 >/.< ).. 82 5 07 *'1( 1 9!() 09(0) !0'(0! ! ) '(*' ) 97*('* 97!(!7 & '09 && (1! *79 *70(&' '(** 9 )&9(' >/.< ).. 82 5 07 *1'(97 9!('* 09(&* !00(07 ! )!'(1) ) 9)*('7 9*'(9! & '09 1)7(07 *79 *&0()' '(99 9 0( 0 >/.< ).. 82 5 07 & 7(*) 9!('* 01(!) !0)(0! ! *0(09 ) 9'*('& 9*0(!7 & '09 197(1 *79 *9'(1* 0(0* 9 !7(9' >/.< ).. 82 5 07 &!9('' 99(!) 01(79 !0 ( ) ! 700(&7 ) 19*(1& 9* ('1 & '09 97*( ) *79 *!!(& '(1) 9 7*9(07 >/.< ).. 82 5 07 1&0(&! 99(!) 01(7) !07(*) ! 71)( ! ) 1&&(&1 9*7()1 & '09 !'&(0! *79 &09( 0 '('! 9 *)0(1' >/.< ).. 82 5 07 9)*(*' 99(7 09('& !0*(!! ! * (0* ) 171() 9**(17 & '09 !&1('9 *79 & 1( ) 0()& 9 *9*( & >/.< ).. 82 5 07 999(!9 !'(71 )'(1& !0&(&' ! *! ('0 ) 1)&(07 9*&( * & '0! ')1('9 *79 &*9('' *( 9 &79(** >/.< ).. 82 5 07 !*)(7' !'( 7 )0(11 !0&(0& ! &*)(00 ) 1' (07 9**(!0 & '0! '9&( *79 &9'(*! 0(&0 9 100(7* >/.< ).. 82 5 0* '0*(! !0(0* )0(&& !0*( ! 100(0 ) &1!(& 9**('9 & '0! 07*(*' *79 1' (&9 0()! 9 117(7' >/.< ).. 82 5 0* '1!(7! !0('9 )0(0' !07('! ! 11'( ' ) &*&(71 9* (97 & '0! )'7(9 *79 1)&(77 '(9! 9 9 1(7) >/.< ).. 82 5 0* 07)(97 !'(11 )'('! !0 ('1 ! 9)!(*! ) & 7(0! 9*)(9) & '0! )&7()1 *79 179( 0 0(&1 9 !''( * >/.< ).. 82 5 0* )'&()' !'()9 01(9 !0)(7! ! 99!(*0 ) &0 (&' 9*)()7 & '0! )7( ) *79 1&9(71 (&* 9 !& (7& >/.< ).. 82 5 0* )1'() 9!(7) 0*(1& !0)(&& ! !*'(9' ) *!*(0' 9*)(70 & '0! 9*(1 *79 19&(** (*' ! ')1(70 >/.< ).. 82 5 0* 7(0' !'(' 0*(*7 !0)(!& 0' '0)( 0 ) *11(91 9*)(10 & '0! 771( 7 *79 9' ( * 0(') ! '!0()* >/.< ).. 82 5 0* !1(7* 99(&0 07(9 !0 (1) 0' '1 (77 ) *&0()9 9* (71 & '0! *'9(*9 *79 90!(*) )(*0 ! 0*7(*9 >/.< ).. 82 5 0* 7&0(*) 99()7 0 (71 !0*(79 0' 0 *(*7 ) *7*(& 9**() & '0! *1'(19 *79 9 7(1* )()' ! )09(& >/.< ).. 82 5 0* *)*(01 99(7! 0 (!! !01()! 0' 0!1( 7 ) * '(*) 9*1('7 & '0! & )(&! *79 97!(7) '(!0 ! )9)()* >/.< ).. 82 5 0* *9!()) 99( & 0*(!! !0!('* 0' )*!(0! ) *0 (!& 9*9(9' & '0! &!7(&7 *79 9&*(** (0 ! 7&()& >/.< ).. 82 5 0* &*)()& 99(!) 01(!1 !)'(** 0' 0!(7& ) 7!*(*& 9&'( ' & '0! 1**(' *79 99 (*7 ()& ! 7'!()' >/.< ).. 82 5 0* 10*(*1 !'(&* 0!(& !)'(1! 0' 1!( ! ) 71*(0& 9&'(*7 & '0! 90*('! *79 !' (*) (1! ! 71)()9 >/.< ).. 82 5 0* 11!(00 9!( * )'()* !)'(1! 0' 7 !(0) ) 7* (7! 9&'(*7 & '0! 917(!& *79 !)7(19 )()1 ! * *(79 >/.< ).. 82 5 0* 97)(!) 99(17 )'()* !)0(9* 0' 7!9(!1 ) 7 0(70 9&0(&' & '0! ! 7(!& *79 !7&(77 '(!& ! *!9(!' >/.< ).. 82 5 0* !'&( ' !'( 7 )'(!9 !))( & 0' **9()! ) 7'!('! 9&)(00 & '0! !!7(7 *79 !&9( 7 )(11 ! &&0(9* >/.< ).. 82 5 0* !&!(90 !'(*! )'(!0 !)0(97 0' &01(&' ) 9&( ! 9&0(*! & ')' '* (9! *79 !!'(& '(70 ! 1)7(9! >/.< ).. 82 5 )* * $ " * +, * * -* - * ! ! ."*"" ! #$%&'()* /* !*+, - . + * ! #$%&'()* 0 . * / ! - 6 8 ! 678 ; 678 435$- 6 8 405$ 6 8 +, 6 8 +, 6 8 0 ./ 68 3/ 68 , 68 675<=8 +0 0& ' *(1! 99()7 )'('& !))(*) 0' &1!(7' ) & ( ' 9&)()1 & ')' 00*(97 *7! '0 ()! (1! ! 1!'(77 >/.< ).. 82 5 0& '!1(9) 9*(9 0!(0' !)*(1 0' 1 1(1& ) 7)(** 9&*(79 & ')' 017( 7 *7! ' (&* 7(09 ! 9*)('! >/.< ).. 82 5 0& 0&'(*& 9&(7* 09(*) !)!(!* 0' 1!1(') ) ))( & 9&!(1' & ')' ) (1) *7! '* (7) 0( * ! !07(71 >/.< ).. 82 5 0& ))7( ) 9*(!& 0!(') ! 7(01 0' 9*1()* ) '0(9! 91 (!) & ')' )!7('! *7! '1 (71 0(0' ! !11(91 >/.< ).. 82 5 0& )91(!! 9*()0 09(99 ! !('1 0' !01()! ) )90()9 919(9) & ')' *7()1 *7! '! (&1 0()' 0' '70(00 >/.< ).. 82 5 0& *0(9) 9*()1 0!(*) !77( 1 0' !11( & ) )&'( & 997(0) & ')' 707(79 *7! 007(01 0('' 0' 0'7(7& >/.< ).. 82 5 0& 70*()0 9 (19 )'('! !*'(7) 00 ' &(1 ) ) 9(!9 9!'(01 & ')' 71 (!9 *7! 0 *(07 )(*) 0' 0&1() >/.< ).. 82 5 0& 719(11 9 (!0 )'(0* !*1() 00 '!&('1 ) )01()7 9!&(!9 & ')' * (7& *7! 0*&(7& '() 0' ) '('1 >/.< ).. 82 5 0& *7)(&! 9*(0* 0!(!0 !& ( ) 00 0**(9* ) 0!*(7* !' ('1 & ')' *! ( ! *7! 011(97 0(!9 0' )! ( 7 >/.< ).. 82 5 0& &'&(7! 9*(*) 0!( ) !&9(*0 00 )0*(1* ) 017(0' !'9()& & ')' &* (7) *7! 0!9(11 0('! 0' *&(& >/.< ).. 82 5 0& &1'(* 9*('! 09(1! !1 (1* 00 )1&('1 ) 0* ()& !0 (*' & ')' 10 (9! *7! )0!(0! 0('& 0' 7)'()' >/.< ).. 82 5 0& 1 (*1 9&()& 09(*0 !19(*0 00 *(& ) 0 (0& !09()& & ')' 11 (*9 *7! ) 9(99 0(!0 0' 79)(9& >/.< ).. 82 5 0& 1!9(0' 9*()9 01(& !9 ()1 00 !&(90 ) 00 ()' !) (') & ')' 9 7(9! *7! )*9(7) )('7 0' *71('* >/.< ).. 82 5 0& 9&)(7* 9 ( * 0&(9' !9!(&7 00 7*1(!1 ) '!7()* !)!( ! & ')' 9!&(01 *7! )1&(!7 ()& 0' &0'(!9 >/.< ).. 82 5 0& !))(1* 9 (7) 01(*9 !!&(*! 00 *0*(0! ) '1&(** ! &( 7 & ')' !* (*0 *7! )!7()* 0()! 0' &1'(19 >/.< ).. 82 5 0& !!7('' 9 (7) 01(*9 7 ''7(1* 00 *9)(&1 ) '**(01 !77(*' & ')0 ')0(0) *7! 0*(0& '('' 0' 170(7) ,E3-3- $ @F $ @ @ Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.09.03 10:21:55 -08'00'Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.09.04 07:41:24 -08'00' Regg, James B (CED) From: James Lott - (C) <jlott@hilcorp.com> Sent: Wednesday, September 2, 2020 7:28 AM�`j To: Regg, James B (CED); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (CED) Cc: Mark O'Malley; William Kruskie; Ian Toomey - (C) Subject: Pre MIT/IA on 1-39 Attachments: Pre MIT -IA 1-39.xlsx James Lott HILCORP Drilling Foreman HILCORP INNOVATION Rig Milne Point, North Slope Alaska 907-670-3094 ilott@hilcorp.com iameslott352(@vahoo.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. 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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.reaa5alaska.00v: AOGCC.Inspeclors0_alaska.gov. phoebebrooksna,alaska.gov chns.wallace_slaska.gov OPERATOR: Hilcorp AK FIELD I UNIT / PAD: Milne Point, Schrader Bluff Oil Pool, I -Pad DATE: OPERATOR REP: AOGCC REP: James Lott Waived By Bob Noble Well MPU -1-39 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. S = Slurry PTD 2200600 Type Inj N Tubing 0 0 N = Not Injecting Form 10-426 (Revised 01/2017) Type Test P Packer TVD 3789 BBL Pump 5.3 IA 0 2630 " 2533 ' 2510 - Interval I Test psi 2500 BBL Return 5.1 OA Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBLPump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) Pre MIT -IA 1-39 FLOOR SAFTY VALVES: BOP STACK: STATE OF ALASKA it p - OIL AND GAS CONSERVATION COMMISSION P.I. Supry Reviewed By: '� Za'7.t7 HOPE Test Report for: WLNE PT UNIT I-39 � Comm Contractor/Rig No.: Hilcorp Innovation - PTD#: 2200600 DATE: 8/22/2020 ' Inspector Guy Cook i Insp Source Operator: Hileorp Alaska, LLC - Operator Rep: S Barber/C Monteque Rig Rep: M Vanhoose/E Evans Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopGDC200821095604 Rams: Type Test: INIT Stripper Annular: Valves: MASP: _. -- 250/3000 250/3000 - 250/3000 - 1338 - Related Insp No: NA- No. Valves 15 P - TEST DATA _ 1 MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: 1 _13 5/8" 5000 - P , P/' Visual Alarm Time/Pressure P/F Location Gen.: - P Trip Tank P '_ P - System Pressure 3100 P Housekeeping: P _ Pit Level Indicators P - P - Pressure After Closure 1450 P - PTD On Location -P Flow Indicator P_ P - 200 PSI Attained 26_ - P Standing Order Posted P _ _ Meth Gas Detector P _ P Full Pressure Attained 98 P Well Sign P H2S Gas Detector P P Blind Switch Covers: All Stations _ - P_ Drl. Rig P MS Misc NA NA Nitgn. Bottles (avg): 692358 P Hazard Sec. P ACC Misc _ NA Misc NA _ —0 - FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1 P_ Stripper 0 --— NA- No. Valves 15 P - Lower Kelly _ 1 FP ✓ Annular Preventer 1 _13 5/8" 5000 - P , Manual Chokes 1 P - Ball Type 2 -_ P #1 Rams 1 2 7/8" x 5.5"-- P- _ Hydraulic Chokes 1 P Inside BOP _I- - _ _P _ #2 Rams I =Blinds P _- CH Misc FSV Misc 0 NA #3 Rams 1 ' 2 7/8" x 5.5" P ._ _ _0 _NA_ #4 Rams _0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams _ 0_ NA (Valid for Coil Rigs Only) Choke Ln. Valves _ 1 31/8"5000, P Quantity P/F HCR Valves _ 2 3 1/8" 5000 FP ✓ Inside Reel Valves 0 NA Kill Line Valves _ 2 _ 3 1/8" 5000 . P Check Valve 0 _ _ NA BOP Misc 0 _ NA Number of Failures: 2 ✓ Test Results Test Time 15 Remarks: 3.5 and 5" test joints used for testing. Lower IBOP failed. Changed out and tested for a pass. HCR choke failed. Serviced valve and retested for a pass. Superchoke was esf ted by flowing through it with the rig pumps at 3bbls/minute and closing/opening the choke. The manual choke was not tested by flowing through it, but by pressuring up on the closed choke and slowly letting it bleed down by working the choke. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-39 Hilcorp Alaska, LLC Permit to Drill Number: 220-060 (revised) Surface Location: 2340' FSL, 3921' FEL, Sec. 33, T13N, R10E, UM, AK Bottomhole Location: 1639' FNL, 578' FEL, Sec. 20, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this 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 August, 2020. y, 10 20 AAC 25.005 REVISED: New Bottom Hole Location 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: 17,280' TVD: 3,980' 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): 60.1' 15. Distance to Nearest Well Open Surface: x-551450 y- 6009454 Zone-4 33.6' to Same Pool: 20' 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole:Surface: 1388 Hole Casing Weight Grade Coupling Length MD TVD MD TVD Driven 20" 129.5# X-52 80' Surface Surface 107' 107' 9-5/8" 47# L-80 TXP 2000' Surface Surface 2000' 1712' 9-5/8" 40# L-80 TXP 4823' 2000' 1712' 6823' 3790' 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 9178' 6673' 3772' 17280' 3980' 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: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 12-1/4" 50-029-23686-00-00 GL / BF Elevation above MSL (ft): See cover letter for other requirements.220-060 (revised) 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): Commission Use Only Effect. Depth MD (ft): Authorized Signature: Production Liner Casing Intermediate Surface Uncemented Screen Liner Stg 1 L - 1353 ft3 / T - 458 ft3 Effect. Depth TVD (ft): Conductor/Structural Length 1731 Total Depth MD (ft):Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Stg 2 L - 1937 ft3 / T - 314 ft3 1192' FNL, 2340' FWL, Sec. 32, T13N, R10E, UM AK 1639' FNL, 578' FEL, Sec. 20, T13N, R10E, UM, AK 88-004 7659 MPU I-39 Milne Point Field Schrader Bluff Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 2340' FSL, 3921' FEL, Sec. 33, T13N, R10E, UM, AK ADL 025906, 025517 & 025515 022224484 4088' 8/7/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Joe Engel joseph.engel@hilcorp.com 777-8395 18. Casing Program:Top - Setting Depth - BottomSpecifications s N ype o W L l R b S Cass os N s No s N o D s s s D 84 o esp G VISED S C 25.0 S SS S s No s No S G y E S s No s Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Digitally signed by Joseph Engel DN: cn=Joseph Engel, ou=Users Date: 2020.08.05 15:36:06 - 08'00' Joseph Engel By Jody Colombie at 10:58 am, Aug 07, 2020 X X MGR07AUG2020 DSR-8/7/2020 X X 1338 psi X X X BOPE test to 3000 psi. Annular to 2500 psi. psi DLB 08/07/2020 G202002022202222222222222 8/10/2020 7/29/2020 Hilcorp Alaska, LLC Page 1 of 1 Joe Engel Drilling Engineer Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email: jengel@hilcorp.com 8.5.2020 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: MPU I-39 (PTD: 220-060) Directional Plan Extension Dear Commissioner, Hilcorp Alaska, LLC hereby submits for review and approval for a modification to the approved Permit to Drill, MP I-39, PTD 220-060. Upon further review by our subsurface team, Hilcorp Alaska wishes to extend the TD of the lateral to 17,280’ MD to reach a further fault block than previously permitted. Drilling operations are intended to commence approximately August 11, 2019, pending rig schedule. All other components of the Permit to Drill (220-060) will remain the same. Please find attached the updated Form 10-401, updated directional plan, updated schematic, and updated AOR Map. No additional wells have been added to the list within the AOR ¼ mile radius as a result of the extension. If you have any questions, or require further information, please do not hesitate to contact myself (Joe Engel) at 777-8395 or jengel@hilcorp.com or Monty Myers at 777-8431 or mmyers@hilcorp.com. Sincerely, Joe Engel Drilling Engineer Area of Review MPI-39 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 Isolation204-119 50-029-23214-00-00 MPU I-14 Oba LateralN/A N/A N/A N/A N/AN/A204-120 50-029-23214-60-00 MPU I-14L1 OA LateralN/A N/A N/A N/A N/AN/A204-121 50-029-23214-61-00 MPU I-14 L2 NB Prod Lateral6870' 3800' N/A N/A Open**Open to Injection Support204-098 50-029-23212-00-00 MPU I-17 NB Prod Lateral4486' 3764' N/A N/A OpenOpen to Injection Support204-099 50-029-23212-60-00 MPU I-17L1 Oba LateralN/A N/A N/A N/A N/ANot Open204-100 50-029-23212-61-00 MPU I-17L2 OA LateralN/A N/A N/A N/A N/ANot Open204-136 50-029-23218-60-00 MPU I-19L1 OA LateralN/A N/A N/A N/A N/ANot Open220-057 50-029-23684-00-00 MPU I-38 Future NB Prod6175' 3760' N/A N/A OpenOpen to Injection SupportTBD TBD MPU I-40 Future NB Prod8200' 3720' N/A N/A Open Open to Injection Support199-17750-029-22497-01-00 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 6,013197-208 50-029-22828-00-00 MPU J-17 SB WINJ6177' 3846' Surface surface OpenWell open to injection support in the NB, NC, OA and OB sands. Packers isolate the NB/NC from the OA/OB.197-220 50-029-22834-00-00 MPU J-18 SB WINJ Shut In7404' 3907' Surface surface Open** NB, OA, Ob sands open.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' MD197-215 50-029-22832-00-00 MPU J-20 P&A Schrader7611' 3796' N/A N/A ClosedP&A'd via sidetrack200-185 50-029-22832-01-00 MPU J-20A SB WINJ Shut InN/A N/A N/A N/A N/ANot Open197-200 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' MD Area of Review MPI-39 SB Nb204-073 50-029-23207-00-00 MPU J-25 P&A'd Lateral4752' 3888' 2497' 2472' ClosedPumped 73 bbls of cmt in NB lateral.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/A N/AN/A N/A N/ANot Open204-067 50-029-23205-61-00 MPU J-26L2** OA LateralN/A N/AN/A N/A N/ANot Open** MPU I-14L1, J-08A, J-18, J-25, J-26/L1/L2 - Future P&A as a part of I-Pad redevelopment. J-05 J J-06 J-09 J-09A J-08 J-08A J-11 J-12 I-08 I-06 J-21 J-17 J-20 J-18 J-22 J-15 I-09 I-10 J-23 J-24 1L1 2L1 J-26 J-26L1 J-26L2 J-25 I-14 I-14L1 I-14L2 I-19 I-19L1 I-18 WSAK 25 I-04AL1 J-01 J-01A J-01AL1 J-03 J-19 J-19A J-16 3LS 3SS J-23A J-24A J-28 J-27 I-39I-40 I-37 HILCORP ALASKA LLC MILNE POINT FIELD AOR MAP I-39 NB Sand Injector (Proposed) FEET 0 1,000 2,000 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 WATER SOURCE REMARKSWell Sybols at top of Schrader Bluff NB Sand Black dash circle = 1320' radius from NB sand in heel and toe of proposed I-39 drill well August 4, 2020 PETRA 8/4/2020 8:35:06 AM _____________________________________________________________________________________ Revised By: JNL 8/3/20 Proposed Schematic Milne Point Unit Well: MPU I-39 PTD: 220-060 API: 50-029-23686-00-00 Depth MD Depth TVD Screen Joint Detail TBD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 129.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 2,000’ 0.0732 9-5/8" Surface 40 / L-80 / TXP 8.679” 2,000’ 6,823’ 0.0758 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.795” 6,673’ 17,280’ 0.0149 TUBING DETAIL 3-1/2" Tubing 9.3 / L-80 / TXP-SR 2.867” Surf 6,673’ 0.0870 JEWELRY DETAIL No Top MD Item ID Upper Completion 1 TBD 3-1/2” XN Nipple, 2.813” Packing Bore, 2.75” No-Go, w/RHC 2.750” 2 TBD 3-1/2” Gauge Mandrel SGM-XPQG w/ ¼” Wire 2.992” 3 TBD 8.25” No Go Locater Sub (2.76’ off No-go) 6.170” 4 TBD 7.375” Tieback above the SLZXP Liner Top Packer 6.170” Lower Completion 5 TBD 7” x 9-5/8” SLZXP Liner Top Packer with 7.38” Seal Bore 6.180” 6 TBD Shoe 3.970” OPEN HOLE / CEMENT DETAIL 42" ±270 ft3 12-1/4" Stg 1 –Lead 1353 ft3 / Tail 458 ft3 Stg 2 –Lead 1937 ft3 / Tail 314 ft3 8-1/2” Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 300’ MD Hole Angle @ XN = TBD ° Hole Angle @ Liner Top = TBD° Max Hole Angle = TBD° 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#: 50-029-23686-00-00 Completed by Innovation: TBD 03 August, 2020 Plan: MPU I-39i wp09 Milne Point M Pt I Pad Plan: MPU I-39i MPU I-39i 075015002250300037504500True Vertical Depth (1500 usft/in)-1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500Vertical Section at 14.00° (1500 usft/in)MPU I-39i wp09 CP3MPU I-39i wp09 ToeMPI-39i wp08 Heel Target - acceptable boundaryMPI-Gaines Mill wp02 HeelMPI-Gaines Mill wp02 CP1MPI-Gaines Mill wp02 CP29 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000600065007000 7500 8000 8500 9000 9500 1000 0 1050 0 11 0 0 0 11 5 00 1200 0 12 500 13000 13500 140 00 1450 0 15 000 15500 16000 165 00 1700 0 17280MPU I-39i wp09Start Dir 3º/100' : 250' MD, 250'TVDStart Dir 4º/100' : 550' MD, 548.77'TVDEnd Dir : 1996.22' MD, 1709.82' TVDStart Dir 4º/100' : 4096.22' MD, 2747.1'TVDEndDir : 4286.95' MD, 2840'TVDStartDir4.5º/100':5108.31'MD, 3233.18'TVDEndDir : 6723.8' MD, 3779.64'TVDStartDir4º/100':6823.8'MD, 3790.09'TVDEndDir : 7029.67' MD, 3802'TVDStartDir2º/100':9455.01'MD, 3828.72'TVDEndDir : 10063.58' MD, 3834.26'TVDStart Dir 2º/100': 11803.68' MD,3849.46'TVDEndDir : 12067.75' MD, 3855.12'TVDTotal Depth:17280.43'MD,3980.1'TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU I-39i33.60+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006009454.03551449.98 70° 26' 11.686 N 149° 34' 49.869 WSURVEY PROGRAMDate: 2020-07-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 900.00 MPU I-39i wp09 (MPU I-39i) 3_Gyro-GC_Csg900.00 6823.80 MPU I-39i wp09 (MPU I-39i) 3_MWD+IFR2+MS+Sag6823.80 17280.43 MPU I-39i wp09 (MPU I-39i) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-39i, True NorthVertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usftMeasured Depth Reference:MPU I-39 As-built RKB @ 60.10usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt I PadWell:Plan: MPU I-39iWellbore:MPU I-39iDesign:MPU I-39i wp09CASING DETAILSTVD TVDSS MD SizeName3790.10 3730.00 6823.91 9-5/8 9 5/8" x 12 1/4"3980.10 3920.00 17280.43 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 0.002 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD3 550.00 9.00 330.00 548.77 20.36 -11.76 3.00 330.00 16.91 Start Dir 4º/100' : 550' MD, 548.77'TVD4 750.00 16.74 320.49 743.62 56.19 -37.95 4.00 -20.00 45.345 1996.22 60.40 273.80 1709.82 242.47 -737.43 4.00 -55.87 56.86 End Dir : 1996.22' MD, 1709.82' TVD6 4096.22 60.40 273.80 2747.10 363.48 -2559.35 0.00 0.00 -266.48 Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD7 4286.95 61.40 282.46 2840.00 387.07 -2724.09 4.00 84.60 -283.44 End Dir : 4286.95' MD, 2840' TVD8 5108.31 61.40 282.46 3233.18 542.65 -3428.25 0.00 0.00 -302.84 Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD9 6723.80 84.00 356.00 3779.64 1649.66 -4296.50 4.50 87.41 561.24 End Dir : 6723.8' MD, 3779.64' TVD10 6823.80 84.00 356.00 3790.09 1748.87 -4303.44 0.00 0.00 655.82 MPI-Gaines Mill wp02 Heel Start Dir 4º/100' : 6823.8' MD, 3790.09'TVD11 7029.67 89.37 2.26 3802.00 1954.19 -4306.53 4.00 49.54 854.30 End Dir : 7029.67' MD, 3802' TVD12 9455.01 89.37 2.26 3828.72 4377.51 -4211.03 0.00 0.00 3228.73 Start Dir 2º/100' : 9455.01' MD, 3828.72'TVD13 9592.31 89.49 5.00 3830.09 4514.50 -4202.35 2.00 87.48 3363.76 MPI-Gaines Mill wp02 CP114 10063.58 89.50 14.43 3834.26 4978.48 -4122.93 2.00 89.99 3833.17 End Dir : 10063.58' MD, 3834.26' TVD15 11803.68 89.50 14.43 3849.46 6663.65 -3689.44 0.00 0.00 5573.15 Start Dir 2º/100' : 11803.68' MD, 3849.46'TVD16 11845.47 88.78 14.00 3850.09 6704.16 -3679.18 2.00 -149.37 5614.94 MPI-Gaines Mill wp02 CP217 12067.75 88.63 18.44 3855.12 6917.48 -3617.11 2.00 92.03 5836.95 End Dir : 12067.75' MD, 3855.12' TVD18 17280.43 88.63 18.44 3980.10 11860.98 -1968.40 0.00 0.00 11032.46 MPU I-39i wp09 Toe Total Depth : 17280.43' MD, 3980.1' TVD -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 South(-)/North(+) (1500 usft/in)-7500 -6750 -6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 West(-)/East(+) (1500 usft/in) MPI-Gaines Mill wp02 CP2 MPI-Gaines Mill wp02 CP1 MPI-Gaines Mill wp02 Heel MPI-39i wp08 Heel Target - acceptable boundary MPU I-39i wp09 Toe MPU I-39i wp09 CP3 9 5/8" x 12 1/4" 4 1/2" x 8 1/2" 25010001500175020002250250027503000325035003750 3980 MPUI-39iwp09 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 550' MD, 548.77'TVD End Dir : 1996.22' MD, 1709.82' TVD Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD End Dir : 4286.95' MD, 2840' TVD Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD End Dir : 6723.8' MD, 3779.64' TVD Start Dir 4º/100' : 6823.8' MD, 3790.09'TVDStart Dir 4º/100' : 6823.8' MD, 3790.09'TVD End Dir : 7029.67' MD, 3802' TVD Start Dir 2º/100' : 9455.01' MD, 3828.72'TVD End Dir : 10063.58' MD, 3834.26' TVD Start Dir 2º/100' : 11803.68' MD, 3849.46'TVD End Dir : 12067.75' MD, 3855.12' TVD Total Depth : 17280.43' MD, 3980.1' TVD CASING DETAILS TVD TVDSS MD Size Name 3790.10 3730.00 6823.91 9-5/8 9 5/8" x 12 1/4" 3980.10 3920.00 17280.43 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt I Pad Well: Plan: MPU I-39i Wellbore: MPU I-39i Plan: MPU I-39i wp09 WELL DETAILS: Plan: MPU I-39i 33.60 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 6009454.03 551449.98 70° 26' 11.686 N 149° 34' 49.869 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU I-39i, True North Vertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usft Measured Depth Reference:MPU I-39 As-built RKB @ 60.10usft 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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-39i usft usft 0.00 0.00 6,009,454.03 551,449.98 33.60Wellhead Elevation:usft0.50 70° 26' 11.686 N 149° 34' 49.869 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-39i Model NameMagnetics IFR 8/17/2020 15.86 80.86 57,374.70000000 Phase:Version: Audit Notes: Design MPU I-39i wp09 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.50 14.000.000.0026.50 8/3/2020 7:35:46PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 -33.60 0.000.000.000.000.000.00250.000.000.00250.00 189.90 330.000.003.003.00-11.7620.36548.77330.009.00550.00 488.67 -20.00-4.763.874.00-37.9556.19743.62320.4916.74750.00 683.52 -55.87-3.753.504.00-737.43242.471,709.82273.8060.401,996.22 1,649.72 0.000.000.000.00-2,559.35363.482,747.10273.8060.404,096.22 2,687.00 84.604.540.524.00-2,724.09387.072,840.00282.4661.404,286.95 2,779.90 0.000.000.000.00-3,428.25542.653,233.18282.4661.405,108.31 3,173.08 87.414.551.404.50-4,296.501,649.663,779.64356.0084.006,723.80 3,719.54 0.000.000.000.00-4,303.441,748.873,790.09356.0084.006,823.80 3,729.99 49.543.042.614.00-4,306.531,954.193,802.002.2689.377,029.67 3,741.90 0.000.000.000.00-4,211.034,377.513,828.722.2689.379,455.01 3,768.62 87.482.000.092.00-4,202.354,514.503,830.095.0089.499,592.31 3,769.99 89.992.000.002.00-4,122.934,978.483,834.2614.4389.5010,063.58 3,774.16 0.000.000.000.00-3,689.446,663.653,849.4614.4389.5011,803.68 3,789.36 -149.37-1.02-1.722.00-3,679.186,704.163,850.0914.0088.7811,845.47 3,789.99 92.032.00-0.072.00-3,617.116,917.483,855.1218.4488.6312,067.75 3,795.02 0.000.000.000.00-1,968.4011,860.983,980.1018.4488.6317,280.43 3,920.00 8/3/2020 7:35:46PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 -33.60 Vert Section 26.50 0.00 26.50 0.00 0.000.00 551,449.986,009,454.03-33.60 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 551,449.986,009,454.0339.90 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 551,449.986,009,454.03139.90 0.00 0.00 250.00 0.00 250.00 0.00 0.000.00 551,449.986,009,454.03189.90 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 300.00 1.50 299.99 0.57 -0.33330.00 551,449.656,009,454.59239.89 3.00 0.47 400.00 4.50 399.85 5.10 -2.94330.00 551,447.006,009,459.11339.75 3.00 4.24 500.00 7.50 499.29 14.15 -8.17330.00 551,441.716,009,468.12439.19 3.00 11.75 550.00 9.00 548.77 20.36 -11.76330.00 551,438.086,009,474.31488.67 3.00 16.91 Start Dir 4º/100' : 550' MD, 548.77'TVD 600.00 10.90 598.01 27.69 -16.33326.38 551,433.466,009,481.60537.91 4.00 22.91 700.00 14.78 695.50 45.61 -29.43321.94 551,420.246,009,499.43635.40 4.00 37.14 750.00 16.74 743.62 56.19 -37.95320.49 551,411.656,009,509.95683.52 4.00 45.34 800.00 17.94 791.35 67.20 -47.96315.11 551,401.566,009,520.89731.25 4.00 53.60 900.00 20.69 885.73 88.58 -73.08306.32 551,376.306,009,542.10825.63 4.00 68.27 1,000.00 23.79 978.29 109.03 -104.87299.62 551,344.376,009,562.32918.19 4.00 80.42 1,100.00 27.12 1,068.58 128.43 -143.17294.43 551,305.946,009,581.461,008.48 4.00 89.98 1,200.00 30.59 1,156.16 146.70 -187.80290.32 551,261.196,009,599.411,096.06 4.00 96.91 1,300.00 34.17 1,240.60 163.74 -238.55286.98 551,210.336,009,616.111,180.50 4.00 101.17 1,400.00 37.83 1,321.49 179.48 -295.16284.21 551,153.626,009,631.451,261.39 4.00 102.75 1,500.00 41.54 1,398.44 193.84 -357.36281.87 551,091.336,009,645.381,338.34 4.00 101.63 1,600.00 45.29 1,471.07 206.74 -424.84279.85 551,023.766,009,657.821,410.97 4.00 97.82 1,700.00 49.07 1,539.03 218.13 -497.28278.07 550,951.256,009,668.701,478.93 4.00 91.35 1,800.00 52.88 1,601.99 227.95 -574.33276.49 550,874.156,009,677.991,541.89 4.00 82.23 1,900.00 56.70 1,659.63 236.14 -655.60275.06 550,792.836,009,685.621,599.53 4.00 70.53 1,996.22 60.40 1,709.82 242.47 -737.43273.80 550,710.976,009,691.381,649.72 4.00 56.86 End Dir : 1996.22' MD, 1709.82' TVD 2,000.00 60.40 1,711.69 242.69 -740.71273.80 550,707.686,009,691.581,651.59 0.00 56.28 2,100.00 60.40 1,761.09 248.45 -827.47273.80 550,620.906,009,696.741,700.99 0.00 40.88 2,200.00 60.40 1,810.48 254.21 -914.23273.80 550,534.116,009,701.901,750.38 0.00 25.49 2,300.00 60.40 1,859.87 259.97 -1,000.99273.80 550,447.326,009,707.071,799.77 0.00 10.09 2,400.00 60.40 1,909.27 265.74 -1,087.74273.80 550,360.536,009,712.231,849.17 0.00 -5.31 2,500.00 60.40 1,958.66 271.50 -1,174.50273.80 550,273.756,009,717.391,898.56 0.00 -20.70 2,600.00 60.40 2,008.06 277.26 -1,261.26273.80 550,186.966,009,722.561,947.96 0.00 -36.10 2,700.00 60.40 2,057.45 283.02 -1,348.02273.80 550,100.176,009,727.721,997.35 0.00 -51.50 2,800.00 60.40 2,106.85 288.78 -1,434.78273.80 550,013.386,009,732.882,046.75 0.00 -66.90 2,900.00 60.40 2,156.24 294.55 -1,521.54273.80 549,926.606,009,738.052,096.14 0.00 -82.29 3,000.00 60.40 2,205.63 300.31 -1,608.29273.80 549,839.816,009,743.212,145.53 0.00 -97.69 3,100.00 60.40 2,255.03 306.07 -1,695.05273.80 549,753.026,009,748.372,194.93 0.00 -113.09 3,200.00 60.40 2,304.42 311.83 -1,781.81273.80 549,666.236,009,753.542,244.32 0.00 -128.49 3,300.00 60.40 2,353.82 317.60 -1,868.57273.80 549,579.456,009,758.702,293.72 0.00 -143.88 3,400.00 60.40 2,403.21 323.36 -1,955.33273.80 549,492.666,009,763.862,343.11 0.00 -159.28 3,500.00 60.40 2,452.60 329.12 -2,042.09273.80 549,405.876,009,769.032,392.50 0.00 -174.68 3,600.00 60.40 2,502.00 334.88 -2,128.84273.80 549,319.086,009,774.192,441.90 0.00 -190.08 3,700.00 60.40 2,551.39 340.65 -2,215.60273.80 549,232.306,009,779.352,491.29 0.00 -205.47 8/3/2020 7:35:46PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 2,540.69 Vert Section 3,800.00 60.40 2,600.79 346.41 -2,302.36273.80 549,145.516,009,784.522,540.69 0.00 -220.87 3,900.00 60.40 2,650.18 352.17 -2,389.12273.80 549,058.726,009,789.682,590.08 0.00 -236.27 4,000.00 60.40 2,699.58 357.93 -2,475.88273.80 548,971.936,009,794.842,639.48 0.00 -251.67 4,096.22 60.40 2,747.10 363.48 -2,559.36273.80 548,888.436,009,799.812,687.00 0.00 -266.48 Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD 4,100.00 60.41 2,748.97 363.70 -2,562.64273.97 548,885.156,009,800.012,688.87 4.01 -267.06 4,200.00 60.87 2,798.01 373.20 -2,649.24278.53 548,798.486,009,808.912,737.91 4.00 -278.80 4,286.95 61.40 2,840.00 387.07 -2,724.09282.46 548,723.556,009,822.272,779.90 4.00 -283.44 End Dir : 4286.95' MD, 2840' TVD 4,300.00 61.40 2,846.24 389.54 -2,735.28282.46 548,712.346,009,824.662,786.14 0.00 -283.75 4,400.00 61.40 2,894.11 408.49 -2,821.01282.46 548,626.496,009,843.012,834.01 0.00 -286.11 4,500.00 61.40 2,941.98 427.43 -2,906.74282.46 548,540.646,009,861.352,881.88 0.00 -288.47 4,600.00 61.40 2,989.85 446.37 -2,992.47282.46 548,454.796,009,879.702,929.75 0.00 -290.84 4,700.00 61.40 3,037.72 465.31 -3,078.20282.46 548,368.946,009,898.052,977.62 0.00 -293.20 4,800.00 61.40 3,085.59 484.25 -3,163.93282.46 548,283.096,009,916.403,025.49 0.00 -295.56 4,900.00 61.40 3,133.46 503.19 -3,249.66282.46 548,197.246,009,934.743,073.36 0.00 -297.92 5,000.00 61.40 3,181.33 522.13 -3,335.39282.46 548,111.396,009,953.093,121.23 0.00 -300.28 5,108.31 61.40 3,233.18 542.65 -3,428.25282.46 548,018.406,009,972.963,173.08 0.00 -302.84 Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD 5,200.00 61.67 3,276.90 563.23 -3,506.15287.14 547,940.376,009,993.013,216.80 4.50 -301.71 5,300.00 62.14 3,324.03 592.93 -3,589.17292.22 547,857.166,010,022.133,263.93 4.50 -292.98 5,400.00 62.79 3,370.28 630.02 -3,669.67297.24 547,776.416,010,058.663,310.18 4.50 -276.47 5,500.00 63.63 3,415.37 674.26 -3,747.15302.19 547,698.636,010,102.363,355.27 4.50 -252.29 5,600.00 64.63 3,459.03 725.38 -3,821.15307.07 547,624.296,010,152.963,398.93 4.50 -220.59 5,700.00 65.78 3,500.99 783.07 -3,891.20311.86 547,553.856,010,210.163,440.89 4.50 -181.56 5,800.00 67.09 3,540.98 846.97 -3,956.86316.56 547,487.756,010,273.603,480.88 4.50 -135.44 5,900.00 68.53 3,578.76 916.69 -4,017.74321.16 547,426.406,010,342.893,518.66 4.50 -82.52 6,000.00 70.09 3,614.11 991.79 -4,073.46325.67 547,370.176,010,417.613,554.01 4.50 -23.13 6,100.00 71.77 3,646.79 1,071.83 -4,123.68330.09 547,319.406,010,497.283,586.69 4.50 42.38 6,200.00 73.54 3,676.61 1,156.29 -4,168.08334.42 547,274.426,010,581.433,616.51 4.50 113.59 6,300.00 75.41 3,703.39 1,244.66 -4,206.40338.68 547,235.506,010,669.523,643.29 4.50 190.07 6,400.00 77.34 3,726.96 1,336.40 -4,238.39342.86 547,202.886,010,761.033,666.86 4.50 271.34 6,500.00 79.34 3,747.17 1,430.94 -4,263.86346.97 547,176.766,010,855.383,687.07 4.50 356.91 6,600.00 81.40 3,763.90 1,527.69 -4,282.65351.03 547,157.316,010,952.003,703.80 4.50 446.25 6,700.00 83.50 3,777.05 1,626.07 -4,294.65355.05 547,144.636,011,050.283,716.95 4.50 538.80 6,723.80 84.00 3,779.64 1,649.66 -4,296.50356.00 547,142.626,011,073.853,719.54 4.50 561.24 End Dir : 6723.8' MD, 3779.64' TVD 6,800.00 84.00 3,787.60 1,725.26 -4,301.78356.00 547,136.816,011,149.403,727.50 0.00 633.31 6,823.80 84.00 3,790.09 1,748.87 -4,303.44356.00 547,135.006,011,173.003,729.99 0.00 655.82 Start Dir 4º/100' : 6823.8' MD, 3790.09'TVD 6,823.91 84.00 3,790.10 1,748.98 -4,303.44356.00 547,134.996,011,173.113,730.00 0.00 655.93 9 5/8" x 12 1/4" 6,900.00 85.98 3,796.74 1,824.67 -4,307.19358.32 547,130.726,011,248.773,736.64 4.01 728.47 7,000.00 88.59 3,801.48 1,924.54 -4,307.461.36 547,129.766,011,348.633,741.38 4.00 825.30 8/3/2020 7:35:46PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 3,741.90 Vert Section 7,029.67 89.37 3,802.00 1,954.19 -4,306.532.26 547,130.496,011,378.283,741.90 4.00 854.30 End Dir : 7029.67' MD, 3802' TVD 7,100.00 89.37 3,802.78 2,024.46 -4,303.762.26 547,132.776,011,448.563,742.68 0.00 923.15 7,200.00 89.37 3,803.88 2,124.38 -4,299.822.26 547,136.026,011,548.493,743.78 0.00 1,021.05 7,300.00 89.37 3,804.98 2,224.30 -4,295.892.26 547,139.276,011,648.423,744.88 0.00 1,118.96 7,400.00 89.37 3,806.08 2,324.21 -4,291.952.26 547,142.526,011,748.353,745.98 0.00 1,216.86 7,500.00 89.37 3,807.19 2,424.13 -4,288.012.26 547,145.776,011,848.293,747.09 0.00 1,314.76 7,600.00 89.37 3,808.29 2,524.04 -4,284.072.26 547,149.016,011,948.223,748.19 0.00 1,412.66 7,700.00 89.37 3,809.39 2,623.96 -4,280.142.26 547,152.266,012,048.153,749.29 0.00 1,510.56 7,800.00 89.37 3,810.49 2,723.88 -4,276.202.26 547,155.516,012,148.083,750.39 0.00 1,608.46 7,900.00 89.37 3,811.59 2,823.79 -4,272.262.26 547,158.766,012,248.013,751.49 0.00 1,706.36 8,000.00 89.37 3,812.69 2,923.71 -4,268.322.26 547,162.006,012,347.943,752.59 0.00 1,804.26 8,100.00 89.37 3,813.80 3,023.63 -4,264.392.26 547,165.256,012,447.883,753.70 0.00 1,902.16 8,200.00 89.37 3,814.90 3,123.54 -4,260.452.26 547,168.506,012,547.813,754.80 0.00 2,000.06 8,300.00 89.37 3,816.00 3,223.46 -4,256.512.26 547,171.756,012,647.743,755.90 0.00 2,097.97 8,400.00 89.37 3,817.10 3,323.38 -4,252.572.26 547,175.006,012,747.673,757.00 0.00 2,195.87 8,500.00 89.37 3,818.20 3,423.29 -4,248.642.26 547,178.246,012,847.603,758.10 0.00 2,293.77 8,600.00 89.37 3,819.30 3,523.21 -4,244.702.26 547,181.496,012,947.533,759.20 0.00 2,391.67 8,700.00 89.37 3,820.40 3,623.12 -4,240.762.26 547,184.746,013,047.463,760.30 0.00 2,489.57 8,800.00 89.37 3,821.51 3,723.04 -4,236.822.26 547,187.996,013,147.403,761.41 0.00 2,587.47 8,900.00 89.37 3,822.61 3,822.96 -4,232.892.26 547,191.236,013,247.333,762.51 0.00 2,685.37 9,000.00 89.37 3,823.71 3,922.87 -4,228.952.26 547,194.486,013,347.263,763.61 0.00 2,783.27 9,100.00 89.37 3,824.81 4,022.79 -4,225.012.26 547,197.736,013,447.193,764.71 0.00 2,881.17 9,200.00 89.37 3,825.91 4,122.71 -4,221.072.26 547,200.986,013,547.123,765.81 0.00 2,979.07 9,300.00 89.37 3,827.01 4,222.62 -4,217.142.26 547,204.226,013,647.053,766.91 0.00 3,076.98 9,400.00 89.37 3,828.12 4,322.54 -4,213.202.26 547,207.476,013,746.983,768.02 0.00 3,174.88 9,455.01 89.37 3,828.72 4,377.50 -4,211.032.26 547,209.266,013,801.963,768.62 0.00 3,228.73 Start Dir 2º/100' : 9455.01' MD, 3828.72'TVD 9,500.00 89.41 3,829.20 4,422.44 -4,208.913.16 547,211.076,013,846.903,769.10 2.00 3,272.85 9,592.31 89.49 3,830.09 4,514.50 -4,202.355.00 547,217.006,013,939.003,769.99 2.00 3,363.76 9,600.00 89.49 3,830.16 4,522.17 -4,201.675.15 547,217.636,013,946.673,770.06 2.00 3,371.37 9,700.00 89.49 3,831.05 4,621.58 -4,190.957.15 547,227.666,014,046.143,770.95 2.00 3,470.42 9,800.00 89.49 3,831.94 4,720.56 -4,176.769.15 547,241.166,014,145.213,771.84 2.00 3,569.89 9,900.00 89.49 3,832.82 4,818.99 -4,159.1411.15 547,258.106,014,243.753,772.72 2.00 3,669.66 10,000.00 89.50 3,833.70 4,916.74 -4,138.0813.15 547,278.486,014,341.633,773.60 2.00 3,769.60 10,063.58 89.50 3,834.26 4,978.48 -4,122.9314.43 547,293.216,014,403.473,774.16 2.00 3,833.17 End Dir : 10063.58' MD, 3834.26' TVD 10,100.00 89.50 3,834.57 5,013.75 -4,113.8614.43 547,302.046,014,438.803,774.47 0.00 3,869.59 10,200.00 89.50 3,835.45 5,110.59 -4,088.9414.43 547,326.286,014,535.803,775.35 0.00 3,969.58 10,300.00 89.50 3,836.32 5,207.44 -4,064.0314.43 547,350.526,014,632.813,776.22 0.00 4,069.58 10,400.00 89.50 3,837.20 5,304.28 -4,039.1214.43 547,374.766,014,729.813,777.10 0.00 4,169.57 10,500.00 89.50 3,838.07 5,401.12 -4,014.2114.43 547,399.006,014,826.813,777.97 0.00 4,269.56 10,600.00 89.50 3,838.94 5,497.97 -3,989.3014.43 547,423.246,014,923.823,778.84 0.00 4,369.56 10,700.00 89.50 3,839.82 5,594.81 -3,964.3914.43 547,447.486,015,020.823,779.72 0.00 4,469.55 10,800.00 89.50 3,840.69 5,691.65 -3,939.4714.43 547,471.726,015,117.823,780.59 0.00 4,569.54 8/3/2020 7:35:46PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 3,781.47 Vert Section 10,900.00 89.50 3,841.57 5,788.50 -3,914.5614.43 547,495.966,015,214.833,781.47 0.00 4,669.54 11,000.00 89.50 3,842.44 5,885.34 -3,889.6514.43 547,520.206,015,311.833,782.34 0.00 4,769.53 11,100.00 89.50 3,843.31 5,982.18 -3,864.7414.43 547,544.446,015,408.833,783.21 0.00 4,869.52 11,200.00 89.50 3,844.19 6,079.03 -3,839.8314.43 547,568.686,015,505.843,784.09 0.00 4,969.52 11,300.00 89.50 3,845.06 6,175.87 -3,814.9114.43 547,592.936,015,602.843,784.96 0.00 5,069.51 11,400.00 89.50 3,845.93 6,272.72 -3,790.0014.43 547,617.176,015,699.843,785.83 0.00 5,169.50 11,500.00 89.50 3,846.81 6,369.56 -3,765.0914.43 547,641.416,015,796.853,786.71 0.00 5,269.50 11,600.00 89.50 3,847.68 6,466.40 -3,740.1814.43 547,665.656,015,893.853,787.58 0.00 5,369.49 11,700.00 89.50 3,848.56 6,563.25 -3,715.2714.43 547,689.896,015,990.853,788.46 0.00 5,469.48 11,803.68 89.50 3,849.46 6,663.65 -3,689.4414.43 547,715.026,016,091.433,789.36 0.00 5,573.16 Start Dir 2º/100' : 11803.68' MD, 3849.46'TVD 11,845.47 88.78 3,850.09 6,704.16 -3,679.1814.00 547,725.006,016,132.003,789.99 2.00 5,614.94 11,900.00 88.74 3,851.27 6,756.93 -3,665.4915.09 547,738.336,016,184.863,791.17 2.00 5,669.46 12,000.00 88.67 3,853.53 6,852.98 -3,637.7817.09 547,765.376,016,281.093,793.43 2.00 5,769.36 12,067.75 88.63 3,855.12 6,917.48 -3,617.1118.44 547,785.596,016,345.723,795.02 2.00 5,836.94 End Dir : 12067.75' MD, 3855.12' TVD 12,100.00 88.63 3,855.90 6,948.06 -3,606.9118.44 547,795.576,016,376.373,795.80 0.00 5,869.09 12,200.00 88.63 3,858.29 7,042.90 -3,575.2918.44 547,826.546,016,471.423,798.19 0.00 5,968.76 12,300.00 88.63 3,860.69 7,137.74 -3,543.6618.44 547,857.526,016,566.463,800.59 0.00 6,068.43 12,400.00 88.63 3,863.09 7,232.57 -3,512.0318.44 547,888.496,016,661.503,802.99 0.00 6,168.10 12,500.00 88.63 3,865.49 7,327.41 -3,480.4018.44 547,919.466,016,756.553,805.39 0.00 6,267.77 12,600.00 88.63 3,867.88 7,422.24 -3,448.7718.44 547,950.436,016,851.593,807.78 0.00 6,367.44 12,700.00 88.63 3,870.28 7,517.08 -3,417.1418.44 547,981.406,016,946.633,810.18 0.00 6,467.11 12,800.00 88.63 3,872.68 7,611.92 -3,385.5118.44 548,012.376,017,041.673,812.58 0.00 6,566.78 12,900.00 88.63 3,875.08 7,706.75 -3,353.8818.44 548,043.346,017,136.723,814.98 0.00 6,666.45 13,000.00 88.63 3,877.47 7,801.59 -3,322.2518.44 548,074.316,017,231.763,817.37 0.00 6,766.12 13,100.00 88.63 3,879.87 7,896.42 -3,290.6318.44 548,105.286,017,326.803,819.77 0.00 6,865.79 13,200.00 88.63 3,882.27 7,991.26 -3,259.0018.44 548,136.256,017,421.843,822.17 0.00 6,965.46 13,300.00 88.63 3,884.67 8,086.10 -3,227.3718.44 548,167.226,017,516.893,824.57 0.00 7,065.13 13,400.00 88.63 3,887.06 8,180.93 -3,195.7418.44 548,198.196,017,611.933,826.96 0.00 7,164.80 13,500.00 88.63 3,889.46 8,275.77 -3,164.1118.44 548,229.176,017,706.973,829.36 0.00 7,264.48 13,600.00 88.63 3,891.86 8,370.60 -3,132.4818.44 548,260.146,017,802.023,831.76 0.00 7,364.15 13,700.00 88.63 3,894.26 8,465.44 -3,100.8518.44 548,291.116,017,897.063,834.16 0.00 7,463.82 13,800.00 88.63 3,896.65 8,560.28 -3,069.2218.44 548,322.086,017,992.103,836.55 0.00 7,563.49 13,900.00 88.63 3,899.05 8,655.11 -3,037.5918.44 548,353.056,018,087.143,838.95 0.00 7,663.16 14,000.00 88.63 3,901.45 8,749.95 -3,005.9618.44 548,384.026,018,182.193,841.35 0.00 7,762.83 14,100.00 88.63 3,903.85 8,844.78 -2,974.3418.44 548,414.996,018,277.233,843.75 0.00 7,862.50 14,200.00 88.63 3,906.25 8,939.62 -2,942.7118.44 548,445.966,018,372.273,846.15 0.00 7,962.17 14,300.00 88.63 3,908.64 9,034.46 -2,911.0818.44 548,476.936,018,467.313,848.54 0.00 8,061.84 14,400.00 88.63 3,911.04 9,129.29 -2,879.4518.44 548,507.906,018,562.363,850.94 0.00 8,161.51 14,500.00 88.63 3,913.44 9,224.13 -2,847.8218.44 548,538.876,018,657.403,853.34 0.00 8,261.18 14,600.00 88.63 3,915.84 9,318.96 -2,816.1918.44 548,569.856,018,752.443,855.74 0.00 8,360.85 14,700.00 88.63 3,918.23 9,413.80 -2,784.5618.44 548,600.826,018,847.493,858.13 0.00 8,460.52 14,800.00 88.63 3,920.63 9,508.64 -2,752.9318.44 548,631.796,018,942.533,860.53 0.00 8,560.19 14,900.00 88.63 3,923.03 9,603.47 -2,721.3018.44 548,662.766,019,037.573,862.93 0.00 8,659.87 8/3/2020 7:35:46PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 3,865.33 Vert Section 15,000.00 88.63 3,925.43 9,698.31 -2,689.6818.44 548,693.736,019,132.613,865.33 0.00 8,759.54 15,100.00 88.63 3,927.82 9,793.14 -2,658.0518.44 548,724.706,019,227.663,867.72 0.00 8,859.21 15,200.00 88.63 3,930.22 9,887.98 -2,626.4218.44 548,755.676,019,322.703,870.12 0.00 8,958.88 15,300.00 88.63 3,932.62 9,982.82 -2,594.7918.44 548,786.646,019,417.743,872.52 0.00 9,058.55 15,400.00 88.63 3,935.02 10,077.65 -2,563.1618.44 548,817.616,019,512.783,874.92 0.00 9,158.22 15,500.00 88.63 3,937.41 10,172.49 -2,531.5318.44 548,848.586,019,607.833,877.31 0.00 9,257.89 15,600.00 88.63 3,939.81 10,267.32 -2,499.9018.44 548,879.556,019,702.873,879.71 0.00 9,357.56 15,700.00 88.63 3,942.21 10,362.16 -2,468.2718.44 548,910.536,019,797.913,882.11 0.00 9,457.23 15,800.00 88.63 3,944.61 10,457.00 -2,436.6418.44 548,941.506,019,892.963,884.51 0.00 9,556.90 15,900.00 88.63 3,947.00 10,551.83 -2,405.0218.44 548,972.476,019,988.003,886.90 0.00 9,656.57 16,000.00 88.63 3,949.40 10,646.67 -2,373.3918.44 549,003.446,020,083.043,889.30 0.00 9,756.24 16,100.00 88.63 3,951.80 10,741.50 -2,341.7618.44 549,034.416,020,178.083,891.70 0.00 9,855.91 16,200.00 88.63 3,954.20 10,836.34 -2,310.1318.44 549,065.386,020,273.133,894.10 0.00 9,955.58 16,300.00 88.63 3,956.59 10,931.18 -2,278.5018.44 549,096.356,020,368.173,896.49 0.00 10,055.25 16,400.00 88.63 3,958.99 11,026.01 -2,246.8718.44 549,127.326,020,463.213,898.89 0.00 10,154.93 16,500.00 88.63 3,961.39 11,120.85 -2,215.2418.44 549,158.296,020,558.253,901.29 0.00 10,254.60 16,600.00 88.63 3,963.79 11,215.68 -2,183.6118.44 549,189.266,020,653.303,903.69 0.00 10,354.27 16,700.00 88.63 3,966.18 11,310.52 -2,151.9818.44 549,220.236,020,748.343,906.08 0.00 10,453.94 16,800.00 88.63 3,968.58 11,405.36 -2,120.3618.44 549,251.216,020,843.383,908.48 0.00 10,553.61 16,900.00 88.63 3,970.98 11,500.19 -2,088.7318.44 549,282.186,020,938.423,910.88 0.00 10,653.28 17,000.00 88.63 3,973.38 11,595.03 -2,057.1018.44 549,313.156,021,033.473,913.28 0.00 10,752.95 17,100.00 88.63 3,975.77 11,689.86 -2,025.4718.44 549,344.126,021,128.513,915.67 0.00 10,852.62 17,200.00 88.63 3,978.17 11,784.70 -1,993.8418.44 549,375.096,021,223.553,918.07 0.00 10,952.29 17,280.43 88.63 3,980.10 11,860.98 -1,968.4018.44 549,400.006,021,300.003,920.00 0.00 11,032.46 Total Depth : 17280.43' MD, 3980.1' TVD - 4 1/2" x 8 1/2" 8/3/2020 7:35:46PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp09 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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. (°) MPU I-39i wp09 Toe 3,980.10 6,021,300.00 549,400.0011,860.98 -1,968.400.00 0.00 -plan hits target center - Point MPI-Gaines Mill wp02 CP2 3,850.09 6,016,132.00 547,725.006,704.16 -3,679.180.00 0.00 -plan hits target center - Point MPI-39i wp08 Heel Target - acceptable bounda 3,790.10 6,011,230.00 547,364.001,804.29 -4,074.030.00 0.00 -plan misses target center by 232.29usft at 6867.65usft MD (3794.24 TVD, 1792.44 N, -4305.97 E) - Polygon 0.00Point 1 6,011,230.00 547,364.003,790.10 0.00 -303.89Point 2 6,010,926.00 547,345.003,790.10 -21.10 -228.17Point 3 6,010,999.00 546,951.003,790.10 -414.62 72.72Point 4 6,011,300.00 546,970.003,790.10 -393.55 MPI-Gaines Mill wp02 Heel 3,790.09 6,011,173.00 547,135.001,748.87 -4,303.440.00 0.00 -plan hits target center - Circle (radius 30.00) MPI-Gaines Mill wp02 CP1 3,830.09 6,013,939.00 547,217.004,514.50 -4,202.350.00 0.00 -plan hits target center - Point MPU I-39i wp09 CP3 3,980.10 6,020,400.00 549,150.0010,962.64 -2,224.630.00 0.00 -plan misses target center by 46.84usft at 16347.44usft MD (3957.73 TVD, 10976.17 N, -2263.49 E) - Point Vertical Depth (usft) Measured Depth (usft) Casing Diameter (") Hole Diameter (")Name Casing Points 4 1/2" x 8 1/2"3,980.1017,280.43 4-1/2 8-1/2 9 5/8" x 12 1/4"3,790.106,823.91 9-5/8 12-1/4 Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 250.00 250.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 550.00 548.77 20.36 -11.76 Start Dir 4º/100' : 550' MD, 548.77'TVD 1,996.22 1,709.82 242.47 -737.43 End Dir : 1996.22' MD, 1709.82' TVD 4,096.22 2,747.10 363.48 -2,559.36 Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD 4,286.95 2,840.00 387.07 -2,724.09 End Dir : 4286.95' MD, 2840' TVD 5,108.31 3,233.18 542.65 -3,428.25 Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD 6,723.80 3,779.64 1,649.66 -4,296.50 End Dir : 6723.8' MD, 3779.64' TVD 6,823.80 3,790.09 1,748.87 -4,303.44 Start Dir 4º/100' : 6823.8' MD, 3790.09'TVD 7,029.67 3,802.00 1,954.19 -4,306.53 End Dir : 7029.67' MD, 3802' TVD 9,455.01 3,828.72 4,377.50 -4,211.03 Start Dir 2º/100' : 9455.01' MD, 3828.72'TVD 10,063.58 3,834.26 4,978.48 -4,122.93 End Dir : 10063.58' MD, 3834.26' TVD 11,803.68 3,849.46 6,663.65 -3,689.44 Start Dir 2º/100' : 11803.68' MD, 3849.46'TVD 12,067.75 3,855.12 6,917.48 -3,617.11 End Dir : 12067.75' MD, 3855.12' TVD 17,280.43 3,980.10 11,860.98 -1,968.40 Total Depth : 17280.43' MD, 3980.1' TVD 8/3/2020 7:35:46PM COMPASS 5000.15 Build 91E Page 9 03 August, 2020Milne PointM Pt I PadPlan: MPU I-39iMPU I-39i5002923686MPU I-39i wp09Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,009,454.03 N, 551,449.98 E (70° 26' 11.69" N, 149° 34' 49.87" W)Datum Height: MPU I-39 As-built RKB @ 60.10usftScan Range: 26.50 to 6,823.80 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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 6,823.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-01 - MPI-01 - MPI-01225.37 26.50 223.80 36.39 143.52526.50Centre Distance Pass - MPI-01 - MPI-01 - MPI-01225.80 176.50 223.64 184.94 104.393176.50Ellipse Separation Pass - MPI-01 - MPI-01 - MPI-01290.66 726.50 284.32 700.00 45.900726.50Clearance Factor Pass - MPI-02 - MPI-02 - MPI-02165.29 253.45 162.57 263.51 60.800253.45Centre Distance Pass - MPI-02 - MPI-02 - MPI-02165.36 276.50 162.48 286.62 57.271276.50Ellipse Separation Pass - MPI-02 - MPI-02 - MPI-02213.14 701.50 206.95 690.88 34.468701.50Clearance Factor Pass - MPI-03 - MPI-03 - MPI-03105.33 26.50 103.76 36.39 67.07826.50Centre Distance Pass - MPI-03 - MPI-03 - MPI-03105.36 51.50 103.72 61.13 64.25751.50Ellipse Separation Pass - MPI-03 - MPI-03 - MPI-03131.30 576.50 126.09 576.58 25.184576.50Clearance Factor Pass - MPI-04 - MPI-04 - MPI-0444.58 26.50 43.01 36.40 28.39126.50Centre Distance Pass - MPI-04 - MPI-04 - MPI-0445.20 251.50 42.50 261.17 16.730251.50Ellipse Separation Pass - MPI-04 - MPI-04 - MPI-0457.14 501.50 52.51 510.32 12.346501.50Clearance Factor Pass - MPI-04 - MPI-04A - MPI-04A44.58 26.50 43.01 36.40 28.39126.50Centre Distance Pass - MPI-04 - MPI-04A - MPI-04A45.20 251.50 42.50 261.17 16.730251.50Ellipse Separation Pass - MPI-04 - MPI-04A - MPI-04A57.14 501.50 52.51 510.32 12.346501.50Clearance Factor Pass - MPI-04 - MPI-04AL1 - MPI-04AL144.58 26.50 43.01 36.40 28.39126.50Centre Distance Pass - MPI-04 - MPI-04AL1 - MPI-04AL145.20 251.50 42.50 261.17 16.730251.50Ellipse Separation Pass - MPI-04 - MPI-04AL1 - MPI-04AL157.14 501.50 52.51 510.32 12.346501.50Clearance Factor Pass - MPI-04 - MPI-04APB1 - MPI-04APB144.58 26.50 43.01 36.40 28.39126.50Centre Distance Pass - MPI-04 - MPI-04APB1 - MPI-04APB145.20 251.50 42.50 261.17 16.730251.50Ellipse Separation Pass - MPI-04 - MPI-04APB1 - MPI-04APB157.14 501.50 52.51 510.32 12.346501.50Clearance Factor Pass - MPI-04 - MPI-04PB1 - MPI-04PB144.58 26.50 43.01 36.40 28.39126.50Centre Distance Pass - MPI-04 - MPI-04PB1 - MPI-04PB145.20 251.50 42.50 261.17 16.730251.50Ellipse Separation Pass - MPI-04 - MPI-04PB1 - MPI-04PB157.14 501.50 52.51 510.32 12.346501.50Clearance Factor Pass - MPI-05 - MPI-05 - MPI-05135.22 252.47 132.91 256.47 58.542252.47Centre Distance Pass - MPI-05 - MPI-05 - MPI-05135.31 276.50 132.87 280.49 55.389276.50Ellipse Separation Pass - MPI-05 - MPI-05 - MPI-05172.20 701.50 167.13 700.18 33.972701.50Clearance Factor Pass - MPI-06 - MPI-06 - MPI-0674.70 258.20 71.97 262.39 27.329258.20Centre Distance Pass - 03 August, 2020-19:38COMPASSPage 2 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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 6,823.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-06 - MPI-06 - MPI-0674.75 276.50 71.88 280.70 26.072276.50Ellipse Separation Pass - MPI-06 - MPI-06 - MPI-0693.42 576.50 88.22 578.59 17.971576.50Clearance Factor Pass - MPI-07 - MPI-07 - MPI-0714.80 183.33 12.69 187.23 7.005183.33Centre Distance Pass - MPI-07 - MPI-07 - MPI-0714.92 226.50 12.58 230.32 6.379226.50Ellipse Separation Pass - MPI-07 - MPI-07 - MPI-0716.81 326.50 13.91 330.19 5.794326.50Clearance Factor Pass - MPI-08 - MPI-08 - MPI-0815.61 101.50 13.46 105.24 7.250101.50Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-0818.36 476.50 14.64 479.40 4.934476.50Clearance Factor Pass - MPI-09 - MPI-09 - MPI-09194.46 172.55 192.03 174.70 80.182172.55Centre Distance Pass - MPI-09 - MPI-09 - MPI-09194.79 251.50 191.55 252.00 60.058251.50Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-091,496.86 3,251.50 1,416.67 3,298.03 18.6663,251.50Clearance Factor Pass - MPI-10 - MPI-10 - MPI-10255.00 26.50 253.16 27.75 138.29226.50Centre Distance Pass - MPI-10 - MPI-10 - MPI-10255.09 76.50 253.10 77.86 127.99676.50Ellipse Separation Pass - MPI-10 - MPI-10 - MPI-10521.69 4,126.50 338.31 4,574.44 2.8454,126.50Clearance Factor Pass - MPI-11 - MPI-11 - MPI-1142.16 425.18 38.93 427.30 13.078425.18Centre Distance Pass - MPI-11 - MPI-11 - MPI-1142.31 451.50 38.92 453.13 12.488451.50Ellipse Separation Pass - MPI-11 - MPI-11 - MPI-11718.92 3,801.50 574.22 3,870.02 4.9683,801.50Clearance Factor Pass - MPI-11 - MPI-11L1 - MPI-11L142.16 425.18 38.93 427.30 13.078425.18Centre Distance Pass - MPI-11 - MPI-11L1 - MPI-11L142.31 451.50 38.92 453.13 12.488451.50Ellipse Separation Pass - MPI-11 - MPI-11L1 - MPI-11L1718.92 3,801.50 574.22 3,870.02 4.9683,801.50Clearance Factor Pass - MPI-12 - MPI-12 - MPI-1256.11 708.60 49.70 708.28 8.757708.60Centre Distance Pass - MPI-12 - MPI-12 - MPI-12178.713,851.5044.824,182.471.3353,851.50Clearance FactorPass - MPI-12 - MPI-12L1 - MPI-12L156.11 708.60 49.70 708.28 8.757708.60Centre Distance Pass - MPI-12 - MPI-12L1 - MPI-12L1178.713,851.5044.984,182.471.3363,851.50Clearance FactorPass - MPI-12 - MPI-12PB1 - MPI-12PB156.11 708.60 49.70 708.28 8.757708.60Centre Distance Pass - MPI-12 - MPI-12PB1 - MPI-12PB1178.713,851.5044.434,182.471.3313,851.50Clearance FactorPass - MPI-13 - MPI-13 - MPI-1397.92 623.74 93.66 617.87 22.987623.74Centre Distance Pass - MPI-13 - MPI-13 - MPI-1398.13 676.50 93.50 668.64 21.220676.50Ellipse Separation Pass - MPI-13 - MPI-13 - MPI-13360.50 3,576.50 225.08 3,680.09 2.6623,576.50Clearance Factor Pass - MPI-14 - MPI-14 - MPI-1494.69 1,070.56 85.78 1,041.75 10.6271,070.56Centre Distance Pass - MPI-14 - MPI-14 - MPI-14168.40 6,276.50 82.99 6,597.95 1.9726,276.50Ellipse Separation Pass - 03 August, 2020-19:38COMPASSPage 3 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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 6,823.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-14 - MPI-14 - MPI-14189.29 6,451.50 91.04 6,769.44 1.9276,451.50Clearance Factor Pass - MPI-14 - MPI-14L1 - MPI-14L194.69 1,070.56 85.78 1,041.75 10.6271,070.56Centre Distance Pass - MPI-14 - MPI-14L1 - MPI-14L1168.40 6,276.50 83.12 6,597.95 1.9756,276.50Ellipse Separation Pass - MPI-14 - MPI-14L1 - MPI-14L1189.29 6,451.50 91.17 6,769.44 1.9296,451.50Clearance Factor Pass - MPI-14 - MPI-14L2 - MPI-14L294.69 1,070.56 85.78 1,041.75 10.6271,070.56Centre Distance Pass - MPI-14 - MPI-14L2 - MPI-14L2168.40 6,276.50 83.14 6,597.95 1.9756,276.50Ellipse Separation Pass - MPI-14 - MPI-14L2 - MPI-14L2189.29 6,451.50 91.19 6,769.44 1.9296,451.50Clearance Factor Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB194.69 1,070.56 85.78 1,041.75 10.6271,070.56Centre Distance Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1168.40 6,276.50 82.86 6,597.95 1.9696,276.50Ellipse Separation Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1189.29 6,451.50 90.91 6,769.44 1.9246,451.50Clearance Factor Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB294.69 1,070.56 85.78 1,041.75 10.6271,070.56Centre Distance Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2168.40 6,276.50 82.86 6,597.95 1.9696,276.50Ellipse Separation Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2189.29 6,451.50 90.91 6,769.44 1.9246,451.50Clearance Factor Pass - MPI-14 - MPI-14PB1 - MPI-14PB194.69 1,070.56 85.78 1,041.75 10.6271,070.56Centre Distance Pass - MPI-14 - MPI-14PB1 - MPI-14PB1168.40 6,276.50 82.99 6,597.95 1.9726,276.50Ellipse Separation Pass - MPI-14 - MPI-14PB1 - MPI-14PB1189.29 6,451.50 91.04 6,769.44 1.9276,451.50Clearance Factor Pass - MPI-14 - MPI-14PB2 - MPI-14PB294.69 1,070.56 85.78 1,041.75 10.6271,070.56Centre Distance Pass - MPI-14 - MPI-14PB2 - MPI-14PB2168.40 6,276.50 82.99 6,597.95 1.9726,276.50Ellipse Separation Pass - MPI-14 - MPI-14PB2 - MPI-14PB2189.29 6,451.50 91.04 6,769.44 1.9276,451.50Clearance Factor Pass - MPI-17 - MPI-17 - MPI-17326.63 5,691.83 229.05 7,409.43 3.3475,691.83Centre Distance Pass - MPI-17 - MPI-17 - MPI-17359.00 5,876.50 194.81 7,542.77 2.1875,876.50Ellipse Separation Pass - MPI-17 - MPI-17 - MPI-17414.14 6,001.50 211.92 7,628.73 2.0486,001.50Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L1339.94 26.50 338.10 34.73 184.09526.50Centre Distance Pass - MPI-17 - MPI-17L1 - MPI-17L1340.13 101.50 338.02 109.32 161.156101.50Ellipse Separation Pass - MPI-17 - MPI-17L1 - MPI-17L1579.50 6,201.50 384.43 7,691.12 2.9716,201.50Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1339.94 26.50 338.10 34.73 184.09526.50Centre Distance Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1507.45 6,101.50 321.44 7,701.56 2.7286,101.50Ellipse Separation Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1555.56 6,201.50 335.68 7,746.00 2.5276,201.50Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L2339.94 26.50 338.10 34.73 184.09526.50Centre Distance Pass - MPI-17 - MPI-17L2 - MPI-17L2340.13 101.50 338.02 109.32161.156101.50Ellipse Separation Pass - MPI-17 - MPI-17L2 - MPI-17L2597.85 6,151.50 372.59 7,728.10 2.6546,151.50Clearance Factor Pass - 03 August, 2020-19:38COMPASSPage 4 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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 6,823.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-19 - MPI-19L1 - MPI-19L1400.17 26.50 398.33 34.30 217.02126.50Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1585.50 1,276.50 574.72 1,316.35 54.3241,276.50Clearance Factor Pass - MPU I-36 - MPU I-36 - MPU I-36239.02 256.33 236.61 256.85 99.330256.33Centre Distance Pass - MPU I-36 - MPU I-36 - MPU I-36239.06 276.50 236.57 277.50 96.104276.50Ellipse Separation Pass - MPU I-36 - MPU I-36 - MPU I-361,173.28 2,776.50 1,149.74 2,901.24 49.8482,776.50Clearance Factor Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1239.02 256.33 236.61 256.85 99.330256.33Centre Distance Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1239.06 276.50 236.57 277.50 96.104276.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB11,173.28 2,776.50 1,149.74 2,901.24 49.8482,776.50Clearance Factor Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2239.02 256.33 236.61 256.85 99.330256.33Centre Distance Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2239.06 276.50 236.57 277.50 96.104276.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB21,173.28 2,776.50 1,149.76 2,901.24 49.8822,776.50Clearance Factor Pass - MPU I-37i - MPU I-37i - MPU I-37i119.36 274.15 116.85 275.32 47.526274.15Centre Distance Pass - MPU I-37i - MPU I-37i - MPU I-37i119.45 301.50 116.82 302.84 45.464301.50Ellipse Separation Pass - MPU I-37i - MPU I-37i - MPU I-37i1,272.15 4,801.50 1,224.14 4,639.48 26.4954,801.50Clearance Factor Pass - MPU I-37i - MPU I-37PB1 - MPU I-37PB1119.36 274.15 116.85 275.32 47.526274.15Centre Distance Pass - MPU I-37i - MPU I-37PB1 - MPU I-37PB1119.45 301.50 116.82 302.84 45.464301.50Ellipse Separation Pass - MPU I-37i - MPU I-37PB1 - MPU I-37PB11,272.15 4,801.50 1,224.13 4,639.48 26.4924,801.50Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03210.14 226.50 207.78 227.40 88.999226.50Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03210.24 276.50 207.68 277.40 82.097276.50Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp031,212.67 3,076.50 1,178.20 3,225.33 35.1713,076.50Clearance Factor Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp03150.41 226.50 148.05 227.40 63.702226.50Centre Distance Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp03150.51 276.50 147.95 277.40 58.772276.50Ellipse Separation Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,479.16 5,026.50 1,420.17 4,900.00 25.0755,026.50Clearance Factor Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp0289.73 568.96 85.69 578.31 22.187568.96Centre Distance Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp0289.82 601.50 85.59 611.95 21.233601.50Ellipse Separation Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02991.67 6,551.50 915.53 6,346.33 13.0246,551.50Clearance Factor Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp0441.33 1,060.45 34.86 1,052.55 6.3931,060.45Centre Distance Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp0441.35 1,076.50 34.83 1,068.41 6.3411,076.50Ellipse Separation Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp04220.51 6,823.80 169.12 6,795.12 4.2916,823.80Clearance Factor Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06118.21 401.50 115.22 397.47 39.447401.50Centre Distance Pass - 03 August, 2020-19:38COMPASSPage 5 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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 6,823.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-26 - MPU I-26 - MPU I-26 wp06118.29 426.50 115.17 420.95 37.841426.50Ellipse Separation Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06492.15 5,776.50 357.25 5,603.61 3.6485,776.50Clearance Factor Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03267.70 226.50 265.34 226.30 113.447226.50Centre Distance Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp03267.74 276.50 265.18 277.43 104.513276.50Ellipse Separation Pass - Plan: MPU I-29 - MPU I-29 - MPU I-29 wp031,031.72 3,101.50 997.60 3,302.74 30.2433,101.50Clearance Factor Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp04180.16 257.74 177.68 259.03 72.511257.74Centre Distance Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp04180.36 351.50 177.45 356.82 61.995351.50Ellipse Separation Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp04623.32 2,951.50 582.77 3,242.10 15.3712,951.50Clearance Factor Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp0329.72 226.50 27.36 227.40 12.587226.50Centre Distance Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp0329.72 251.50 27.26 252.40 12.088251.50Ellipse Separation Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp03522.67 4,276.50 426.51 4,368.16 5.4354,276.50Clearance Factor Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp0580.89 563.94 76.94 559.57 20.489563.94Centre Distance Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp0580.94 576.50 76.93 571.31 20.172576.50Ellipse Separation Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp05280.29 5,251.50 132.56 5,321.13 1.8975,251.50Clearance Factor Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05154.52 333.96 151.72 331.17 55.055333.96Centre Distance Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05154.55 351.50 151.67 347.51 53.563351.50Ellipse Separation Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05716.37 5,776.50 583.69 5,517.42 5.3995,776.50Clearance Factor Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp0929.59 367.41 26.62 366.60 9.976367.41Centre Distance Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp0929.60 376.50 26.60 375.56 9.840376.50Ellipse Separation Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09726.07 4,526.50 613.93 4,514.41 6.4744,526.50Clearance Factor Pass - Rig: MPU I-38 - MPU I-38 - MPU I-3858.30 280.75 55.79 281.56 23.207280.75Centre Distance Pass - Rig: MPU I-38 - MPU I-38 - MPU I-3858.36 301.50 55.76 302.27 22.455301.50Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38605.19 3,901.50 532.45 4,172.58 8.3203,901.50Clearance Factor Pass - Rig: MPU I-38 - MPU I-38PB1 - MPU I-38PB158.30 280.75 55.79 281.56 23.207280.75Centre Distance Pass - Rig: MPU I-38 - MPU I-38PB1 - MPU I-38PB158.36 301.50 55.76 302.27 22.455301.50Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38PB1 - MPU I-38PB1605.19 3,901.50 532.45 4,172.58 8.3203,901.50Clearance Factor Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38PB258.30 280.75 55.79 281.56 23.207280.75Centre Distance Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38PB258.36 301.50 55.76 302.27 22.455301.50Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38PB2605.19 3,901.50 532.45 4,172.58 8.3203,901.50Clearance Factor Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38 wp1158.30 280.75 56.00 281.56 25.363280.75Centre Distance Pass - 03 August, 2020-19:38COMPASSPage 6 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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 6,823.80 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningRig: MPU I-38 - MPU I-38PB2 - MPU I-38 wp1158.36 301.50 55.98 302.27 24.465301.50Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38 wp11605.19 3,901.50 532.67 4,172.58 8.3453,901.50Clearance Factor Pass - M Pt J PadSurvey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 900.00 MPU I-39i wp09 3_Gyro-GC_Csg900.00 6,823.80 MPU I-39i wp09 3_MWD+IFR2+MS+Sag6,823.80 17,280.43 MPU I-39i wp09 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.03 August, 2020-19:38COMPASSPage 7 of 9 0.001.002.003.004.00Separation Factor0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPI-12No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.WELL DETAILS:Plan: MPU I-39i NAD 1927 (NADCON CONUS)Alaska Zone 04+N/-S + Longitude0.0033.60E/-WNorthingEastingLatittude0.006009454.03551449.98 70° 26' 11.686 N149° 34' 49.869 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-39i, True NorthVertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usftMeasured Depth Reference:MPU I-39 As-built RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-07-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 900.00 MPU I-39i wp09 (MPU I-39i) 3_Gyro-GC_Csg900.00 6823.80 MPU I-39i wp09 (MPU I-39i) 3_MWD+IFR2+MS+Sag6823.80 17280.43 MPU I-39i wp09 (MPU I-39i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPI-03MPI-04MPI-06MPI-07MPI-08MPI-11MPI-12MPI-13MPU I-37iMPU I-24 wp02MPU I-25i wp04MPU I-25i wp04MPU I-26 wp06MPU I-31 wp03MPU I-32i wp05MPU I-40 wp09MPU I-38MPU I-38 wp11NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 17280.43Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-39iWellbore: MPU I-39iPlan: MPU I-39i wp09Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3790.10 3730.00 6823.91 9-5/8 9 5/8" x 12 1/4"3980.10 3920.00 17280.43 4-1/2 4 1/2" x 8 1/2" 03 August, 2020Milne PointM Pt I PadPlan: MPU I-39iMPU I-39i5002923686MPU I-39i wp09Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,009,454.03 N, 551,449.98 E (70° 26' 11.69" N, 149° 34' 49.87" W)Datum Height: MPU I-39 As-built RKB @ 60.10usftScan Range: 6,823.80 to 17,280.43 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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: 6,823.80 to 17,280.43 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-09 - MPI-09 - MPI-091,337.61 8,723.80 1,072.28 7,675.65 5.0418,723.80Clearance Factor Pass - MPI-09 - MPI-09 - MPI-091,132.89 9,423.80 959.14 8,164.99 6.5219,423.80Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-091,095.77 9,870.74 988.13 8,452.42 10.1809,870.74Centre Distance Pass - MPI-12 - MPI-12 - MPI-121,319.59 6,823.80 1,088.98 6,470.84 5.7226,823.80Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L11,319.59 6,823.80 1,089.35 6,470.84 5.7316,823.80Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB11,319.59 6,823.80 1,088.43 6,470.84 5.7096,823.80Clearance Factor Pass - MPI-14 - MPI-14 - MPI-14304.78 6,823.80 172.27 7,128.19 2.3006,823.80Clearance Factor Pass - MPI-14 - MPI-14L1 - MPI-14L1304.78 6,823.80 172.40 7,128.19 2.3026,823.80Clearance Factor Pass - MPI-14 - MPI-14L2 - MPI-14L2281.21 6,823.80 178.02 7,175.40 2.7256,823.80Clearance Factor Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1292.14 6,823.80 173.21 7,147.03 2.4566,823.80Ellipse Separation Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1430.87 7,173.80 237.29 7,391.00 2.2267,173.80Clearance Factor Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2281.21 6,823.80 177.74 7,175.40 2.7186,823.80Clearance Factor Pass - MPI-14 - MPI-14PB1 - MPI-14PB1304.78 6,823.80 172.27 7,128.19 2.3006,823.80Clearance Factor Pass - MPI-14 - MPI-14PB2 - MPI-14PB2304.78 6,823.80 172.27 7,128.19 2.3006,823.80Clearance Factor Pass - MPI-17 - MPI-17 - MPI-171,081.07 6,823.80 824.51 8,097.68 4.2146,823.80Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L11,086.88 6,823.80 842.42 7,918.02 4.4466,823.80Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB11,087.91 6,823.80 835.56 7,746.00 4.3116,823.80Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L21,133.93 6,823.80 855.63 8,004.46 4.0746,823.80Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1447.44 13,298.80 212.33 12,225.00 1.90313,298.80Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1394.54 13,423.80 197.14 12,225.00 1.99913,423.80Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1377.20 13,539.47 209.12 12,225.00 2.24413,539.47Centre Distance Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,288.77 15,448.80 1,053.96 13,977.74 5.48915,448.80Clearance Factor Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,283.86 15,523.80 1,051.71 13,977.74 5.53015,523.80Ellipse Separation Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,283.00 15,570.54 1,052.74 13,977.74 5.57215,570.54Centre Distance Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02529.03 16,023.80 280.90 15,403.63 2.13216,023.80Clearance Factor Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02528.30 16,051.61 283.24 15,403.63 2.15616,051.61Centre Distance Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp04174.01 9,381.58 121.48 9,354.30 3.3139,381.58Centre Distance Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp04174.58 9,448.80 121.12 9,418.65 3.2669,448.80Ellipse Separation Pass - 03 August, 2020-19:39COMPASSPage 2 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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: 6,823.80 to 17,280.43 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-25i - MPU I-25i - MPU I-25i wp04305.99 16,073.80 141.73 15,880.73 1.86316,073.80Clearance Factor Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06780.53 15,662.95 552.36 16,628.00 3.42115,662.95Centre Distance Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06782.90 15,723.80 549.36 16,628.00 3.35215,723.80Ellipse Separation Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06802.35 15,848.80 558.53 16,628.00 3.29115,848.80Clearance Factor Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp041,121.57 17,280.43 840.10 16,237.47 3.98517,280.43Clearance Factor Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp03385.66 17,280.43 149.05 17,107.14 1.63017,280.43Clearance Factor Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp05155.59 9,999.18 94.90 10,416.95 2.5649,999.18Centre Distance Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp05176.32 12,048.80 94.51 12,471.26 2.15512,048.80Ellipse Separation Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp05273.84 17,280.43 99.01 17,701.66 1.56617,280.43Clearance Factor Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05902.70 12,181.36 754.55 13,402.10 6.09312,181.36Centre Distance Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05903.41 17,280.43 627.97 18,501.05 3.28017,280.43Clearance Factor Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09930.84 12,965.01 759.53 14,743.15 5.43412,965.01Centre Distance Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09957.24 15,623.80 715.25 17,342.25 3.95615,623.80Ellipse Separation Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09978.13 15,773.80 726.78 17,342.25 3.89115,773.80Clearance Factor Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38762.10 13,448.80 598.61 12,865.91 4.66113,448.80Clearance Factor Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38760.76 13,498.80 598.28 12,892.74 4.68213,498.80Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38760.63 13,519.96 598.53 12,904.54 4.69313,519.96Centre Distance Pass - Rig: MPU I-38 - MPU I-38PB1 - MPU I-38PB11,039.22 8,423.80 958.06 8,097.65 12.8048,423.80Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38PB1 - MPU I-38PB11,039.09 8,450.31 958.76 8,111.34 12.9358,450.31Centre Distance Pass - Rig: MPU I-38 - MPU I-38PB1 - MPU I-38PB11,110.69 9,873.80 963.02 9,459.00 7.5219,873.80Clearance Factor Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38PB2943.27 12,048.80 773.49 11,575.00 5.55612,048.80Clearance Factor Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38PB2932.21 12,148.80 767.51 11,575.00 5.66012,148.80Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38PB2930.63 12,203.06 768.58 11,575.00 5.74312,203.06Centre Distance Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38 wp11797.85 13,359.13 620.96 12,734.66 4.51013,359.13Centre Distance Pass - Rig: MPU I-38 - MPU I-38PB2 - MPU I-38 wp11832.64 15,398.80 601.82 14,800.00 3.60715,398.80Clearance Factor Pass - M Pt J PadMPJ-08 - MPJ-08 - MPJ-081,495.48 16,473.80 1,160.54 8,593.00 4.46516,473.80Clearance Factor Pass - MPJ-08 - MPJ-08 - MPJ-081,478.86 16,598.80 1,153.58 8,593.00 4.54616,598.80Ellipse Separation Pass - MPJ-08 - MPJ-08 - MPJ-081,472.67 16,734.00 1,160.22 8,593.00 4.71316,734.00Centre Distance Pass - MPJ-08 - MPJ-08A - MPJ-08A209.27 13,373.14 145.89 7,798.38 3.30213,373.14Centre Distance Pass - 03 August, 2020-19:39COMPASSPage 3 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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: 6,823.80 to 17,280.43 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-08 - MPJ-08A - MPJ-08A215.30 13,423.80 144.98 7,795.65 3.06213,423.80Ellipse Separation Pass - MPJ-08 - MPJ-08A - MPJ-08A386.71 13,698.80 190.06 7,780.87 1.96713,698.80Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-091,496.20 13,498.80 1,307.74 6,398.30 7.93913,498.80Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-091,408.72 14,173.80 1,253.89 7,060.67 9.09814,173.80Ellipse Separation Pass - MPJ-09 - MPJ-09 - MPJ-091,401.19 14,373.95 1,262.48 7,211.03 10.10214,373.95Centre Distance Pass - MPJ-09 - MPJ-09A - MPJ-09A169.47 13,009.53 108.22 7,329.69 2.76713,009.53Centre Distance Pass - MPJ-09 - MPJ-09A - MPJ-09A173.20 13,048.80 106.88 7,313.21 2.61113,048.80Ellipse Separation Pass - MPJ-09 - MPJ-09A - MPJ-09A276.34 13,248.80 137.25 7,234.36 1.98713,248.80Clearance Factor Pass - MPJ-15 - MPJ-15 - MPJ-151,231.86 15,448.80 916.47 7,145.00 3.90615,448.80Clearance Factor Pass - MPJ-15 - MPJ-15 - MPJ-151,175.64 15,698.80 887.26 7,145.00 4.07715,698.80Ellipse Separation Pass - MPJ-15 - MPJ-15 - MPJ-151,166.58 15,844.49 899.03 7,145.00 4.36015,844.49Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17205.26 11,348.15 120.90 6,420.69 2.43311,348.15Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17206.85 11,373.80 120.81 6,420.98 2.40411,373.80Ellipse Separation Pass - MPJ-17 - MPJ-17 - MPJ-17364.01 11,648.80 158.26 6,424.14 1.76911,648.80Clearance Factor Pass - MPJ-18 - MPJ-18 - MPJ-1835.9914,615.15-48.897,350.030.42414,615.15Centre DistanceFAIL - MPJ-18 - MPJ-18 - MPJ-1879.2714,698.80-124.007,395.380.39014,698.80Clearance FactorFAIL - MPJ-18 - MPJ-18 - MPJ-18158.6114,798.80-224.287,451.510.41414,798.80Ellipse SeparationFAIL - MPJ-19 - MPJ-19 - MPJ-19398.63 12,373.80 253.11 6,669.27 2.73912,373.80Clearance Factor Pass - MPJ-19 - MPJ-19 - MPJ-19276.83 12,623.80 204.25 6,725.72 3.81412,623.80Ellipse Separation Pass - MPJ-19 - MPJ-19 - MPJ-19272.78 12,672.22 205.52 6,736.71 4.05612,672.22Centre Distance Pass - MPJ-19 - MPJ-19A - MPJ-19A1,497.33 11,873.80 1,360.32 5,750.00 10.92911,873.80Clearance Factor Pass - MPJ-19 - MPJ-19A - MPJ-19A1,430.56 12,298.80 1,312.71 5,750.00 12.13912,298.80Ellipse Separation Pass - MPJ-19 - MPJ-19A - MPJ-19A1,430.03 12,337.74 1,313.44 5,750.00 12.26512,337.74Centre Distance Pass - MPJ-20 - MPJ-20 - MPJ-201,028.80 9,573.80 789.19 7,108.21 4.2949,573.80Clearance Factor Pass - MPJ-20 - MPJ-20 - MPJ-20737.80 10,148.80 631.14 6,963.74 6.91810,148.80Ellipse Separation Pass - MPJ-20 - MPJ-20 - MPJ-20724.05 10,295.84 637.85 6,909.36 8.40010,295.84Centre Distance Pass - MPJ-20 - MPJ-20A - MPJ-20A1,233.99 9,373.80 1,016.75 6,858.72 5.6809,373.80Clearance Factor Pass - MPJ-20 - MPJ-20A - MPJ-20A832.49 10,273.80 767.20 6,554.27 12.75110,273.80Ellipse Separation Pass - MPJ-20 - MPJ-20A - MPJ-20A830.60 10,334.70 768.07 6,530.69 13.28410,334.70Centre Distance Pass - MPJ-23 - MPJ-23 - MPJ-231,068.69 10,048.80 831.69 6,423.75 4.50910,048.80Clearance Factor Pass - 03 August, 2020-19:39COMPASSPage 4 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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: 6,823.80 to 17,280.43 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-23 - MPJ-23 - MPJ-23722.35 10,773.80 643.35 6,278.21 9.14510,773.80Ellipse Separation Pass - MPJ-23 - MPJ-23 - MPJ-23716.93 10,864.85 645.37 6,255.80 10.01810,864.85Centre Distance Pass - MPJ-23 - MPJ-23A - MPJ-23A1,068.69 10,048.80 823.84 6,431.25 4.36510,048.80Clearance Factor Pass - MPJ-23 - MPJ-23A - MPJ-23A725.70 10,748.80 643.00 6,291.95 8.77510,748.80Ellipse Separation Pass - MPJ-23 - MPJ-23A - MPJ-23A716.93 10,864.85 645.30 6,263.30 10.00910,864.85Centre Distance Pass - MPJ-23 - MPJ-23L1 - MPJ-23L11,068.69 10,048.80 831.69 6,423.75 4.50910,048.80Clearance Factor Pass - MPJ-23 - MPJ-23L1 - MPJ-23L1722.35 10,773.80 643.35 6,278.21 9.14510,773.80Ellipse Separation Pass - MPJ-23 - MPJ-23L1 - MPJ-23L1716.93 10,864.85 645.37 6,255.80 10.01810,864.85Centre Distance Pass - MPJ-24 - MPJ-24A - MPJ-24A716.92 12,373.80 639.68 6,132.30 9.28212,373.80Ellipse Separation Pass - MPJ-24 - MPJ-24A - MPJ-24A716.89 12,380.16 639.68 6,132.15 9.28512,380.16Centre Distance Pass - MPJ-24 - MPJ-24A - MPJ-24A1,069.19 13,173.80 834.08 6,106.16 4.54813,173.80Clearance Factor Pass - MPJ-24 - MPJ-24L1 - MPJ-24L1716.92 12,373.80 639.68 6,136.01 9.28212,373.80Ellipse Separation Pass - MPJ-24 - MPJ-24L1 - MPJ-24L1716.89 12,380.16 639.68 6,135.86 9.28612,380.16Centre Distance Pass - MPJ-24 - MPJ-24L1 - MPJ-24L11,069.19 13,173.80 837.11 6,109.87 4.60713,173.80Clearance Factor Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB1716.92 12,373.80 639.68 6,136.01 9.28212,373.80Ellipse Separation Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB1716.89 12,380.16 639.68 6,135.86 9.28612,380.16Centre Distance Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB11,069.19 13,173.80 836.87 6,109.87 4.60213,173.80Clearance Factor Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB2716.92 12,373.80 639.68 6,136.01 9.28212,373.80Ellipse Separation Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB2716.89 12,380.16 639.68 6,135.86 9.28612,380.16Centre Distance Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB21,069.19 13,173.80 837.12 6,109.87 4.60713,173.80Clearance Factor Pass - MPJ-24 - MPU J-24 - MPJ-24716.92 12,373.80 639.68 6,136.01 9.28212,373.80Ellipse Separation Pass - MPJ-24 - MPU J-24 - MPJ-24716.89 12,380.16 639.68 6,135.86 9.28612,380.16Centre Distance Pass - MPJ-24 - MPU J-24 - MPJ-241,069.19 13,173.80 837.12 6,109.87 4.60713,173.80Clearance Factor Pass - MPJ-25 - MPJ-25 - MPJ-255.8213,099.53-57.147,412.300.09213,099.53Clearance FactorFAIL - MPJ-25 - MPJ-25 - MPJ-2594.9313,198.80-177.627,440.800.34813,198.80Ellipse SeparationFAIL - MPJ-26 - MPJ-26 - MPJ-262.169,961.11-53.817,070.000.0399,961.11Clearance FactorFAIL - MPJ-26 - MPJ-26 - MPJ-2612.529,973.80-109.467,072.960.1039,973.80Ellipse SeparationFAIL - MPJ-26 - MPJ-26L1 - MPJ-26L1355.09 9,673.80 172.45 7,024.01 1.9449,673.80Clearance Factor Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1175.12 9,973.80 124.90 7,064.77 3.4879,973.80Ellipse Separation Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1174.65 9,986.79 124.96 7,066.48 3.5159,986.79Centre DistancePass - 03 August, 2020-19:39COMPASSPage 5 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp09Comparison 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: 6,823.80 to 17,280.43 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp09MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-26 - MPJ-26L2 - MPJ-26L2232.59 9,823.80 100.93 6,961.83 1.7679,823.80Clearance Factor Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2120.61 10,023.80 70.42 7,035.29 2.40310,023.80Ellipse Separation Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2119.38 10,042.58 70.68 7,042.84 2.45110,042.58Centre Distance Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB12.169,961.11-53.977,070.000.0399,961.11Clearance FactorFAIL - MPJ-26 - MPJ-26PB1 - MPJ-26PB112.529,973.80-109.617,072.960.1039,973.80Ellipse SeparationFAIL - MPJ-26 - MPJ-26PB2 - MPJ-26PB22.169,961.11-53.977,070.000.0399,961.11Clearance FactorFAIL - MPJ-26 - MPJ-26PB2 - MPJ-26PB212.529,973.80-109.617,072.960.1039,973.80Ellipse SeparationFAIL - MPJ-27 - MPJ-27 - MPJ-27735.95 11,458.10 675.28 6,399.02 12.13011,458.10Ellipse Separation Pass - MPJ-27 - MPJ-27 - MPJ-271,050.96 12,198.80 897.10 6,387.06 6.83112,198.80Clearance Factor Pass - MPJ-28 - MPJ-28 - MPJ-281,081.10 9,423.80 930.67 6,722.64 7.1879,423.80Clearance Factor Pass - MPJ-28 - MPJ-28 - MPJ-28769.01 10,123.80 709.84 6,641.98 12.99810,123.80Ellipse Separation Pass - MPJ-28 - MPJ-28 - MPJ-28767.62 10,171.10 710.35 6,631.93 13.40410,171.10Centre Distance Pass - Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 900.00 MPU I-39i wp09 3_Gyro-GC_Csg900.00 6,823.80 MPU I-39i wp09 3_MWD+IFR2+MS+Sag6,823.80 17,280.43 MPU I-39i wp09 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.03 August, 2020-19:39COMPASSPage 6 of 8 0.001.002.003.004.00Separation Factor7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200 15675Measured Depth (950 usft/in)MPU MPJ-18MPJ-26No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.WELL DETAILS:Plan: MPU I-39i NAD 1927 (NADCON CONUS)Alaska Zone 0433.60+N/-S +E/-W Northing Easting Latittude Longitude0.000.006009454.03551449.98 70° 26' 11.686 N149° 34' 49.869 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-39i, True NorthVertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usftMeasured Depth Reference:MPU I-39 As-built RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-07-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 900.00 MPU I-39i wp09 (MPU I-39i) 3_Gyro-GC_Csg900.00 6823.80 MPU I-39i wp09 (MPU I-39i) 3_MWD+IFR2+MS+Sag6823.80 17280.43 MPU I-39i wp09 (MPU I-39i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200 15675Measured Depth (950 usft/in)MPJ-26MPJ-26PB1MPJ-26PB2NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 17280.43Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-39iWellbore: MPU I-39iPlan: MPU I-39i wp09Ladder / S.F. Plots2 of 2CASING DETAILSTVD TVDSS MD Size Name3790.10 3730.00 6823.91 9-5/8 9 5/8" x 12 1/4"3980.10 3920.00 17280.43 4-1/2 4 1/2" x 8 1/2" $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $ $) $) $) $) $)$) $)$) $)$)$) $)$)$) $) $)$)$) $)$)$) $) $) $) $)$)$) $)$) $)$) $) $) $) $) $) $)$) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $ $$) $) $) $)$) $) $) $) $) !!! !! !!! !!! ! !! !!! ! !!!! ! ! !! !!! !!!!!!! !!! ! !!!!!!!!!! ! !!!!!! !!!!!! ! !!! !! !! ! ! !!!! ! ! !!!!!!!!! !! !! !!!!!!!!! D $) MPU I-39i_SHL MPU I-39i_TPH MPU I-39i_BHL N-01 N-01A J-05 J-07 J-06 J-09 J-09A J-08 J-08A J-10 J-11 J-12 J-13 I-05 G-10 G-15 I-08 I-06 J-21 J-17 J-20 J-20A J-22 J-15 I-09 I-10 G-14 G-14L1 I-15 I-15L1 G-17 G-18G-18L1 J-26 J-26L1 J-26L2 J-25 I-17 I-17L1 I-17L2 I-14I-14L1 I-14L2 I-19 I-19L1 I-16 H-18 H-18L1 H-18L2 H-16 H-16L1 H-15I-18 WSAK 25 I-01 I-02 I-03 I-04 I-04A I-04AL1 J-01 J-01AJ-01AL1 J-02 J-03 J-04 G-05 G-08 G-08A I-07 J-19 J-19A J-24L1PB1 I-15PB1 J-26PB1 J-25PB1 I-17L1PB1 I-14PB1 I-19PB1 H-16PB1 I-04PB1 J-26PB2 I-14PB2 I-19PB2 H-16PB2 I-04APB1 I-14L2PB1 H-16PB3 I-14L2PB2 G-17LS I-02LS G-17SS I-02SS M-12 M-11 M-14 M-15 M-13 M-12PB2 M-16 M-17 M-35 I-35 I-36 L-60PB1 L-61 wp07 I-20 I-36PB1 I-36PB2 L-60 L-60PB2 I-37PB1 I-37 KUPARUK RIVER UNIT MILNE POINT UNITADL025517 ADL025515 ADL315848 ADL025906 ADL025628 ADL025627 Sec. 20 Sec. 29 Sec. 33 Sec. 22 Sec. 21 Sec. 2 Sec. 5 Sec. 34 Sec. 3 Sec. 28 Sec. 32 Sec. 27 Sec. 4 Sec. 30 (636) Sec. 31 (639) Sec. 19 (633) U012N010E U013N010E MPU J MPU I Map Date: 8/5/2020 Milne Point Unit MPI-39 Well wp09 E0 1,000 2,000 3,000 Feet Legend !MPU I-39i_SHL D MPU I-39i_TPH $)MPU I-39i_BHL !Other Surface Holes (SHL) $)Other Bottom Holes (BHL) Other Well Paths Oil and Gas Unit Boundary Pad Footprint Document Path: O:\Alaska\GIS\north_slope\data\wells\TRS_Distance\mxds\2020\NorthSlope_MPI_39_wp09.mxd Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. MPU I-39 (injector) 220-060 X Milne Point Schrader Bluff Oil X X WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:MILNE PT UNIT I-39Initial Class/TypeSER / 1WINJGeoArea890Unit On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2200600MILNE POINT, SCHRADER BLFF OIL - 525140NA1 Permit fee attachedYes Surface location in ADL 25906; top prod int in ADL 25517;2 Lease number appropriateYes TD in ADL 25515.3 Unique well name and numberYes Milne Point Schrader Bluff Oil Pool (525140), governed by CO 477, amended by CO 477.05.4 Well located in a defined poolYes CO 477.05 specifies: “There are no restrictions as to well spacing except that no pay shall5 Well located proper distance from drilling unit boundaryYes be opened in a well closer than 500 feet from the exterior boundary of the affected area.”6 Well located proper distance from other wellsYes As planned, well conforms to spacing requirements.7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes Area Injection Order No. 10-B14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes MPU I-14, I-14L1, I-14L2, I17, I-17L1, I-19L1, I-38, I-40,15 All wells within 1/4 mile area of review identified (For service well only)No J-08A, J-09, J-09A, J-17, J018, J-19, J-20, J-20A, J-25,16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA J-26, J-26L1, J-26L217 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 20" conductor, driven to 107'18 Conductor string providedYes19 Surface casing protects all known USDWsYes 9-5/8" casing to be cemented with 2 stage cement job20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes 47# 9-5/8" casing over the permafrost, 40# 9-5/8" casing below the permafrost23 Casing designs adequate for C, T, B & permafrostYes Innovation rig in ongoin operations24 Adequate tankage or reserve pitNA New grassroots well.25 If a re-drill, has a 10-403 for abandonment been approvedYes Close approaches to other SB wells in the production interval. No close approaches in surface hole.26 Adequate wellbore separation proposedYes 16" diverter line below 3 ram stack and annular27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes 1 annular, 3 ram stack tested to 3000 psi29 BOPEs, do they meet regulationYes 5M stack30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo No H2S is present on MPU I pad33 Is presence of H2S gas probableYes Area of review performed, offset wells included with PTD request34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S not anticipated from drilling of offset wells. Rig has H2S sensors and alarms.35 Permit can be issued w/o hydrogen sulfide measuresYes Hydrates may be encountered (see p. 14). Mitigation discussed on p. 45-46. Lost circulation possible;36 Data presented on potential overpressure zonesNA mitigation discussed on p. 45-46. Managed Pressure Drilling technique may be used if abnormal37 Seismic analysis of shallow gas zonesNA pressure is encountered; faults may be crossed (see p. 47-48); lost circulation material will38 Seabed condition survey (if off-shore)NA be available at the drill site.39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate7/27/2020ApprMGRDate8/10/2020ApprSFDDate7/27/2020AdministrationEngineeringGeologyGeologic Commissioner:DTSDate:7/29/2020Engineering Commissioner:JLCDate7/29/2020Public CommissionerJMPDate7/29/2020Planned mud program appears adequate to control operator's forecast formation pressures. Revised directional plan. >500' original MD.8/10/2020 8/10/20208/10/2020 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-39 Hilcorp Alaska, LLC Permit to Drill Number: 220-060 Surface Location: 2340’ FSL, 3921’ FEL, Sec. 33, T13N, R10E, UM, AK Bottomhole Location: 2323’ FSL, 1152’ FEL, Sec. 20, 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 July, 2020. Sincerely, 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: 15,851' TVD: 3,935' 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): 60.1' 15. Distance to Nearest Well Open Surface: x-551450 y- 6009454 Zone-4 33.6' to Same Pool: 20' 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole:Surface: 1388 Hole Casing Weight Grade Coupling Length MD TVD MD TVD Driven 20" 129.5# X-52 80' Surface Surface 107' 107' 9-5/8" 47# L-80 TXP 2000' Surface Surface 2000' 1712' 9-5/8" 40# L-80 TXP 4823' 2000' 1712' 6823' 3790' 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 9178' 6673' 3772' 15851' 3935' 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 4088' 8/7/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Joe Engel joseph.engel@hilcorp.com 777-8395 18. Casing Program:Top - Setting Depth - BottomSpecifications MPU I-39 Milne Point Field Schrader Bluff Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 2340' FSL, 3921' FEL, Sec. 33, T13N, R10E, UM, AK ADL 025906, 025517 & 025515 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 4087, FSL, 2940' FEL, Sec. 32, T13N, R10E, UM AK 2323' FSL, 1152' FEL, Sec. 20, T13N, R10E, UM, AK 88-004 7659 1731 Total Depth MD (ft):Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Stg 1 L - 1353 ft3 / T - 458 ft3 Effect. Depth TVD (ft): Conductor/Structural Length Uncemented Screen Liner Production Liner Casing Intermediate Commission Use Only Effect. Depth MD (ft): Authorized Signature: 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. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): 12-1/4" s N ype o W L l R b S Cass os N s No s N o D s s s D 84 o esp G S S 20 SS S s No s No S G y E S s No s Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 7.22.2020 By Jody Colombie at 8:19 am, Jul 23, 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: 2020.07.22 19:22:06 -08'00' Monty M Myers 1338 psipsi 220-060 SFD 7/27/2020 DSR-7/23/2020 BOPE test to 3000 psi. Annular to 2500 psi. 50-029-23686-00-00 MGR29JUL2020R29JJJJJJJJJJJJJJJJJUL2020 7/29/2020 J 2120 2829 32 J-05 J J-06 J-09 J-09A J-08 J-08A J-11 J-12 I-08 I-06 J-21 J-17 J-20 J-18 J-22 J-15 I-09 I-10 J-23 J-24 1L1 2L1 J-26 J-26L1 J-26L2 J-25 I-17 I-17L1 I-14 I-14L1 I-14L2 I-19 I-19L1 I-16 I-18 WSAK 25 I-04AL1 J-01 J-01A J-01AL1 J-03 J-19 J-19A J-16 3LS 3SS I-02SS J-23A J-24A J-28 J-27 I-39I-40 I-37 HILCORP ALASKA LLC MILNE POINT FIELD AOR MAP I-39 NB Sand Injector (Proposed) FEET 0 1,000 2,000 POSTED WELL DATA Well Number WELL SYMBOLS Active Oil Location Shut In Oil INJ Well (Water Flood) P&A Oil Abandoned Injector Producer Location Shut In INJ WATER SOURCE REMARKSWell Sybols at top of Schrader Bluff NB Sand Black dash circle = 1320' radius from NB sand in heel and toe of proposed I-39 drill well July 15, 2020 PETRA 7/15/2020 5:16:13 PM Area of Review MPI-39 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 Isolation204-119 50-029-23214-00-00 MPU I-14 Oba LateralN/A N/A N/A N/A N/AN/A204-120 50-029-23214-60-00 MPU I-14L1 OA LateralN/A N/A N/A N/A N/AN/A204-121 50-029-23214-61-00 MPU I-14 L2 NB Prod Lateral6870' 3800' N/A N/A Open**Open to Injection Support204-098 50-029-23212-00-00 MPU I-17 NB Prod Lateral4486' 3764' N/A N/A OpenOpen to Injection Support204-099 50-029-23212-60-00 MPU I-17L1 Oba LateralN/A N/A N/A N/A N/ANot Open204-100 50-029-23212-61-00 MPU I-17L2 OA LateralN/A N/A N/A N/A N/ANot Open204-136 50-029-23218-60-00 MPU I-19L1 OA LateralN/A N/A N/A N/A N/ANot Open220-057 50-029-23684-00-00 MPU I-38 Future NB Prod6175' 3760' N/A N/A OpenOpen to Injection SupportTBD TBD MPU I-40 Future NB Prod8200' 3720' N/A N/A Open Open to Injection Support199-17750-029-22497-01-00 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 6,013197-208 50-029-22828-00-00 MPU J-17 SB WINJ6177' 3846' Surface surface OpenWell open to injection support in the NB, NC, OA and OB sands. Packers isolate the NB/NC from the OA/OB.197-220 50-029-22834-00-00 MPU J-18 SB WINJ Shut In7404' 3907' Surface surface Open** NB, OA, Ob sands open.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' MD197-215 50-029-22832-00-00 MPU J-20 P&A Schrader7611' 3796' N/A N/A ClosedP&A'd via sidetrack200-185 50-029-22832-01-00 MPU J-20A SB WINJ Shut InN/A N/A N/A N/A N/ANot Open197-200 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' MD19 9-1 17 19 5-1 59 Area of Review MPI-39 SB Nb204-073 50-029-23207-00-00 MPU J-25 P&A'd Lateral4752' 3888' 2497' 2472' ClosedPumped 73 bbls of cmt in NB lateral.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/A N/AN/A N/A N/ANot Open204-067 50-029-23205-61-00 MPU J-26L2** OA LateralN/A N/AN/A N/A N/ANot Open** MPU I-14L1, J-08A, J-18, J-25, J-26/L1/L2 - Future P&A as a part of I-Pad redevelopment. Milne Point Unit (MPU) I-39 Drilling Program Version 1 7/20/2020 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-39 SB Injector Drilling Procedure 1.0 Well Summary Well MPU I-39 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 15,850’ MD / 3,935’ TVD PBTD, MD / TVD 15,840’ MD / 3,935’ TVD Surface Location (Governmental) 2340' FSL, 3921’ FEL, Sec 33, T13N, R10E, UM, AK Surface Location (NAD 27) X= 551,450 Y= 6,009,454 Top of Productive Horizon (Governmental) 4087' FSL, 2940' FEL, Sec 32, T13N, R10E, UM, AK TPH Location (NAD 27) X= 547,135 Y= 6,011,173 BHL (Governmental) 2323' FSL, 1152' FEL, Sec 20, T13N, R10E, UM, AK BHL (NAD 27) X= 548,838 Y=6,019,979 AFE Number 2012655 AFE Drilling Days 18 days AFE Completion Days 3 days AFE Drilling Amount $ 3,924,155 AFE Completion Amount $ 1,547,629 AFE Facility Amount $ 292,800 Maximum Anticipated Pressure (Surface) 1338 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1,731 psig Work String 5”, 19.5#, S-135, NC 50 KB Elevation above MSL: 26.5 ft + 31.7 ft = 58.2 ft GL Elevation above MSL: 31.7 ft BOP Equipment 13-5/8” x 5M Annular, (3) ea 13-5/8” x 5M Rams 60.1' per directional survey SFD 7/23/202033.6' Page 3 Milne Point Unit I-39 SB Injector Drilling Procedure 2.0 Management of Change Information Page 4 Milne Point Unit I-39 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-39 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, nathan.sperry@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 nathan.sperry@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 nathan.sperry@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 Drilling Engineer Nathan Sperry 907.777.8450 907-301-8996 nathan.sperry@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomey@hilcorp.com Geologist Rebecca Emerson 907.590.0648 rebecca.emerson@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-39 SB Injector Drilling Procedure 6.0 Planned Wellbore Schematic Page 7 Milne Point Unit I-39 SB Injector Drilling Procedure 7.0 Drilling / Completion Summary MPU I-39 is a grassroots injector planned to be drilled in the Schrader Bluff Nb sand. I-39 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” 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 August 7th, 2020, pending rig schedule. Surface casing will be run to 6,824’ MD / 3,935’ 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-39 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-39. 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-39 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-39 SB Injector Drilling Procedure 9.0 RU and Preparatory Work 9.1 I-39 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-39 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-39 SB Injector Drilling Procedure 10.4 Rig & Diverter Orientation: *Orientation may differ on location Page 13 Milne Point Unit I-39 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-39 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-39 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 ALDACIDE G 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 0.1 ppb Page 16 Milne Point Unit I-39 SB Injector Drilling Procedure 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-39 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-39 SB Injector Drilling Procedure 12.5 Float equipment and Stage tool equipment drawings: Page 19 Milne Point Unit I-39 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-39 SB Injector Drilling Procedure Page 21 Milne Point Unit I-39 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-39 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-39 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 (5,823' - 2,500') x .0558 bpf x 1.3 = 241.1 1353.4 Total Lead 241.1 1353.4 12-1/4" OH x 9-5/8" Casing (6,823' - 5,823') 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 575 sx 394 sx Page 24 Milne Point Unit I-39 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 ) + (4,203’ x .0758 bpf )= 186.75 + 318.6 = 505.35 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 (.07321 * 2000) + ((6823-120-2000) * .0758) = 502.9 Page 25 Milne Point Unit I-39 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-39 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 439 sx 270 sx Page 27 Milne Point Unit I-39 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. ((2500 -2000) * .0758) + (2000 * .07321) = 184.3 bbls Page 28 Milne Point Unit I-39 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-39 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. FIT & Casing Test Digital Data to AOGCC Page 30 Milne Point Unit I-39 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-39 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 J-18 – SB Injector, SI. Has perfs open in OA, OB, NB Sand. We will watch for magnetic interference when drilling past. J-18 will be abandoned as part of the I pad redevelopment. 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. 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. Page 32 Milne Point Unit I-39 SB Injector Drilling Procedure 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. 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. Page 33 Milne Point Unit I-39 SB Injector Drilling Procedure 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-39 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 screen joints, the following well control response procedure will be followed: x With screen joint 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 screens. 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 brine (to keep from plugging screens with solids) x Install screen joints 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 screen joint body x Screen joint placement ±40’ x The screen joint 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-39 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-39 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-39 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-39 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. ~ 6000' MD is planned 70° inclination Page 39 Milne Point Unit I-39 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. 24 hour notice to AOGCC Page 40 Milne Point Unit I-39 SB Injector Drilling Procedure 18.0 Innovation Rig Diverter Schematic Page 41 Milne Point Unit I-39 SB Injector Drilling Procedure 19.0 Innovation Rig BOP Schematic Page 42 Milne Point Unit I-39 SB Injector Drilling Procedure 20.0 Wellhead Schematic Page 43 Milne Point Unit I-39 SB Injector Drilling Procedure 21.0 Days Vs Depth Page 44 Milne Point Unit I-39 SB Injector Drilling Procedure 22.0 Formation Tops & Information MPU i-39 Formations (wp08) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2175 -1740 1801 792.44 8.46 LA3 5170 -3200 3261 1434.84 8.46 Ugnu MB 2690 -3435 3496 1538.24 8.46 Schrader Bluff NA 6555 -3695 3756 1652.64 8.46 Schrader Bluff NB 6895 -3730 3791 1668.04 8.46 Page 45 Milne Point Unit I-39 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-39 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-39 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: Faults may be crossed on this well. 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 J-18 – SB Injector, SI. Has perfs open in OA, OB, NB Sand. We will watch for magnetic interference when drilling past. J-18 will be abandonded as part of the I pad redevelopment 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. Page 48 Milne Point Unit I-39 SB Injector Drilling Procedure 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. Page 49 Milne Point Unit I-39 SB Injector Drilling Procedure 24.0 Innovation Rig Layout Page 50 Milne Point Unit I-39 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-39 SB Injector Drilling Procedure 26.0 Innovation Rig Choke Manifold Schematic Page 52 Milne Point Unit I-39 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: 1338 psi (see attached M ASP determination & calculation) 1338 psi (see attached M ASP 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 6,823 0 3,790 6,823 15,850 3,790 3,935 6,823 9,027 40 13.5 L-80 L-80 TXP H625 272,920 121,865 272,920 121,865 916 307 3.36 2.52 1,872 1,944 3,090 8,540 1.65 4.39 1,338 1,338 5,750 9,020 4.30 6.74 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) DATE: 7/22/2020 WELL: MPU I-39 DESIGN BY: Joe Engel Hole Size Hole Size Casing Section Design Criteria: Calculation & Casing Design Factors Calculation/Specification Casing OD Bottom (MD) Bottom (TVD) Top (MD) MASP: Drilling Mode MASP: Hole Size Worst 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 Page 53 Milne Point Unit I-39 SB Injector Drilling Procedure 28.0 8-1/2” Hole Section MASP MD TVD Planned Top: 6823 3790 Planned TD: 15850 3935 Anticipated Formations and Pressures: Formation Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff NB Sand 1731 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 i-37 SB NB 8.9 - 9.2 Surface 3988 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: 3935 (ft) x 0.78(psi/ft)= 3070 3070(psi) - [0.1(psi/ft)*3935(ft)]= 2676 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff sand) 3935 (ft) x 0.44(psi/ft)= 1732 psi 1732(psi) - 0.1(psi/ft)*3935(ft) 1338 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-39 Milne Point Unit TVD 3,935 Page 54 Milne Point Unit I-39 SB Injector Drilling Procedure 29.0 Spider Plot (NAD 27) (Governmental Sections) Page 55 Milne Point Unit I-39 SB Injector Drilling Procedure 30.0 Surface Plat (As Staked) (NAD 27) 20 July, 2020 Plan: MPU I-39i wp08 Milne Point M Pt I Pad Plan: MPU I-39i MPU I-39i 075015002250300037504500True Vertical Depth (1500 usft/in)-1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500Vertical Section at 14.00° (1500 usft/in)MPI-Gaines Mill wp02 HeelMPI-Gaines Mill wp02 CP1MPI-Gaines Mill wp02 CP2MPI-Gaines Mill wp02 Toe9 5/8" x 12 1/4"4 1/2" x 8 1/2"500100015002000250030003500400045005000600065007000 7500 8000 8500 9000 9500 10000 10500 11 000 11 5 0 0 12000 1250 0 1300 0 1350 0 14000 14500 15 000 15 500 15 8 5 1MPU I-39i wp08Start Dir 3º/100' : 250' MD, 250'TVDStart Dir 4º/100' : 550' MD, 548.77'TVDEnd Dir : 1996.22' MD, 1709.82' TVDStart Dir 4º/100' : 4096.22' MD, 2747.1'TVDEndDir : 4286.95' MD, 2840'TVDStartDir4.5º/100':5108.31'MD, 3233.18'TVDEndDir : 6723.8' MD, 3779.64'TVDStartDir4º/100':6823.8'MD, 3790.09'TVDEndDir :7030.17' MD, 3802.03'TVDStartDir3º/100':9501.59'MD, 3829.19'TVDEndDir :9893.67' MD, 3832.76'TVDStart Dir 3º/100' : 11820.9'MD, 3849.73'TVDEnd Dir :11930.05' MD,3851.9' TVDTotal Depth:15850.88' MD,3935.09'TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU I-39i33.60+N/-S +E/-WNorthingEastingLatittudeLongitude0.000.006009454.03551449.98 70° 26' 11.686 N 149° 34' 49.869 WSURVEY PROGRAMDate: 2020-07-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool26.50 900.00 MPU I-39i wp08 (MPU I-39i) 3_Gyro-GC_Csg900.00 6823.91 MPU I-39i wp08 (MPU I-39i) 3_MWD+IFR2+MS+Sag6823.91 15850.88 MPU I-39i wp08 (MPU I-39i) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-39i, True NorthVertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usftMeasured Depth Reference:MPU I-39 As-built RKB @ 60.10usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt I PadWell:Plan: MPU I-39iWellbore:MPU I-39iDesign:MPU I-39i wp08CASING DETAILSTVD TVDSS MD SizeName3790.10 3730.00 6823.91 9-5/8 9 5/8" x 12 1/4"3935.09 3874.99 15850.88 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 0.002 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD3 550.00 9.00 330.00 548.77 20.36 -11.76 3.00 330.00 16.91 Start Dir 4º/100' : 550' MD, 548.77'TVD4 750.00 16.74 320.49 743.62 56.19 -37.95 4.00 -20.00 45.345 1996.22 60.40 273.80 1709.82 242.47 -737.43 4.00 -55.87 56.86 End Dir : 1996.22' MD, 1709.82' TVD6 4096.22 60.40 273.80 2747.10 363.48 -2559.35 0.00 0.00 -266.48 Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD7 4286.95 61.40 282.46 2840.00 387.07 -2724.09 4.00 84.60 -283.44 End Dir : 4286.95' MD, 2840' TVD8 5108.31 61.40 282.46 3233.18 542.65 -3428.25 0.00 0.00 -302.84 Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD9 6723.80 84.00 356.00 3779.64 1649.66 -4296.50 4.50 87.41 561.24 End Dir : 6723.8' MD, 3779.64' TVD10 6823.80 84.00 356.00 3790.09 1748.87 -4303.44 0.00 0.00 655.82 MPI-Gaines Mill wp02 Heel Start Dir 4º/100' : 6823.8' MD, 3790.09'TVD11 7030.17 89.37 2.28 3802.03 1954.69 -4306.49 4.00 49.65 854.79 End Dir : 7030.17' MD, 3802.03' TVD12 9501.59 89.37 2.28 3829.19 4424.01 -4208.10 0.00 0.00 3274.56 Start Dir 3º/100' : 9501.59' MD, 3829.19'TVD13 9592.29 89.49 5.00 3830.09 4514.50 -4202.35 3.00 87.49 3363.76 MPI-Gaines Mill wp02 CP114 9893.67 89.50 14.04 3832.76 4811.41 -4152.55 3.00 90.00 3663.90 End Dir : 9893.67' MD, 3832.76' TVD15 11820.90 89.50 14.04 3849.73 6680.98 -3684.97 0.00 0.00 5591.05 Start Dir 3º/100' : 11820.9' MD, 3849.73'TVD16 11844.79 88.78 14.00 3850.09 6704.16 -3679.18 3.00 -176.66 5614.94 MPI-Gaines Mill wp02 CP217 11930.05 88.78 16.56 3851.90 6786.38 -3656.72 3.00 89.93 5700.16 End Dir : 11930.05' MD, 3851.9' TVD18 15850.88 88.78 16.56 3935.09 10543.76 -2539.55 0.00 0.00 9616.19 MPI-Gaines Mill wp02 Toe Total Depth : 15850.88' MD, 3935.09' TVD -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 South(-)/North(+) (1500 usft/in)-7500 -6750 -6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 West(-)/East(+) (1500 usft/in) MPI-Gaines Mill wp02 Toe MPI-Gaines Mill wp02 CP2 MPI-Gaines Mill wp02 CP1 MPI-Gaines Mill wp02 Heel 9 5/8" x 12 1/4" 4 1/2" x 8 1/2"7501250150017502000225027503000325035003 7 5 0 3935 MPUI-39iwp08 Start Dir 3º/100' : 250' MD, 250'TVD Start Dir 4º/100' : 550' MD, 548.77'TVD End Dir : 1996.22' MD, 1709.82' TVD Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD End Dir : 4286.95' MD, 2840' TVD Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD End Dir : 6723.8' MD, 3779.64' TVD Start Dir 4º/100' : 6823.8' MD, 3790.09'TVD End Dir : 7030.17' MD, 3802.03' TVD Start Dir 3º/100' : 9501.59' MD, 3829.19'TVD End Dir : 9893.67' MD, 3832.76' TVD Start Dir 3º/100' : 11820.9' MD, 3849.73'TVD End Dir : 11930.05' MD, 3851.9' TVD Total Depth : 15850.88' MD, 3935.09' TVD CASING DETAILS TVD TVDSS MD Size Name 3790.10 3730.00 6823.91 9-5/8 9 5/8" x 12 1/4" 3935.09 3874.99 15850.88 4-1/2 4 1/2" x 8 1/2" Project: Milne Point Site: M Pt I Pad Well: Plan: MPU I-39i Wellbore: MPU I-39i Plan: MPU I-39i wp08 WELL DETAILS: Plan: MPU I-39i 33.60 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 6009454.03 551449.98 70° 26' 11.686 N 149° 34' 49.869 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well Plan: MPU I-39i, True North Vertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usft Measured Depth Reference:MPU I-39 As-built RKB @ 60.10usft 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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-39i usft usft 0.00 0.00 6,009,454.03 551,449.98 33.60Wellhead Elevation:usft0.50 70° 26' 11.686 N 149° 34' 49.869 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU I-39i Model NameMagnetics BGGM2020 10/7/2020 15.83 80.83 57,363.62340421 Phase:Version: Audit Notes: Design MPU I-39i wp08 PLAN Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.50 14.000.000.0026.50 7/20/2020 5:09:27PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 -33.60 0.000.000.000.000.000.00250.000.000.00250.00 189.90 330.000.003.003.00-11.7620.36548.77330.009.00550.00 488.67 -20.00-4.763.874.00-37.9556.19743.62320.4916.74750.00 683.52 -55.87-3.753.504.00-737.43242.471,709.82273.8060.401,996.22 1,649.72 0.000.000.000.00-2,559.35363.482,747.10273.8060.404,096.22 2,687.00 84.604.540.524.00-2,724.09387.072,840.00282.4661.404,286.95 2,779.90 0.000.000.000.00-3,428.25542.653,233.18282.4661.405,108.31 3,173.08 87.414.551.404.50-4,296.501,649.663,779.64356.0084.006,723.80 3,719.54 0.000.000.000.00-4,303.441,748.873,790.09356.0084.006,823.80 3,729.99 49.653.042.604.00-4,306.491,954.693,802.032.2889.377,030.17 3,741.93 0.000.000.000.00-4,208.104,424.013,829.192.2889.379,501.59 3,769.09 87.493.000.133.00-4,202.354,514.503,830.095.0089.499,592.29 3,769.99 90.003.000.003.00-4,152.554,811.413,832.7614.0489.509,893.67 3,772.66 0.000.000.000.00-3,684.976,680.983,849.7314.0489.5011,820.90 3,789.63 -176.66-0.17-2.993.00-3,679.186,704.163,850.0914.0088.7811,844.79 3,789.99 89.933.000.013.00-3,656.726,786.383,851.9016.5688.7811,930.05 3,791.80 0.000.000.000.00-2,539.5510,543.763,935.0916.5688.7815,850.88 3,874.99 7/20/2020 5:09:27PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 -33.60 Vert Section 26.50 0.00 26.50 0.00 0.000.00 551,449.986,009,454.03-33.60 0.00 0.00 100.00 0.00 100.00 0.00 0.000.00 551,449.986,009,454.0339.90 0.00 0.00 200.00 0.00 200.00 0.00 0.000.00 551,449.986,009,454.03139.90 0.00 0.00 250.00 0.00 250.00 0.00 0.000.00 551,449.986,009,454.03189.90 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 300.00 1.50 299.99 0.57 -0.33330.00 551,449.656,009,454.59239.89 3.00 0.47 400.00 4.50 399.85 5.10 -2.94330.00 551,447.006,009,459.11339.75 3.00 4.24 500.00 7.50 499.29 14.15 -8.17330.00 551,441.716,009,468.12439.19 3.00 11.75 550.00 9.00 548.77 20.36 -11.76330.00 551,438.086,009,474.31488.67 3.00 16.91 Start Dir 4º/100' : 550' MD, 548.77'TVD 600.00 10.90 598.01 27.69 -16.33326.38 551,433.466,009,481.60537.91 4.00 22.91 700.00 14.78 695.50 45.61 -29.43321.94 551,420.246,009,499.43635.40 4.00 37.14 750.00 16.74 743.62 56.19 -37.95320.49 551,411.656,009,509.95683.52 4.00 45.34 800.00 17.94 791.35 67.20 -47.96315.11 551,401.566,009,520.89731.25 4.00 53.60 900.00 20.69 885.73 88.58 -73.08306.32 551,376.306,009,542.10825.63 4.00 68.27 1,000.00 23.79 978.29 109.03 -104.87299.62 551,344.376,009,562.32918.19 4.00 80.42 1,100.00 27.12 1,068.58 128.43 -143.17294.43 551,305.946,009,581.461,008.48 4.00 89.98 1,200.00 30.59 1,156.16 146.70 -187.80290.32 551,261.196,009,599.411,096.06 4.00 96.91 1,300.00 34.17 1,240.60 163.74 -238.55286.98 551,210.336,009,616.111,180.50 4.00 101.17 1,400.00 37.83 1,321.49 179.48 -295.16284.21 551,153.626,009,631.451,261.39 4.00 102.75 1,500.00 41.54 1,398.44 193.84 -357.36281.87 551,091.336,009,645.381,338.34 4.00 101.63 1,600.00 45.29 1,471.07 206.74 -424.84279.85 551,023.766,009,657.821,410.97 4.00 97.82 1,700.00 49.07 1,539.03 218.13 -497.28278.07 550,951.256,009,668.701,478.93 4.00 91.35 1,800.00 52.88 1,601.99 227.95 -574.33276.49 550,874.156,009,677.991,541.89 4.00 82.23 1,900.00 56.70 1,659.63 236.14 -655.60275.06 550,792.836,009,685.621,599.53 4.00 70.53 1,996.22 60.40 1,709.82 242.47 -737.43273.80 550,710.976,009,691.381,649.72 4.00 56.86 End Dir : 1996.22' MD, 1709.82' TVD 2,000.00 60.40 1,711.69 242.69 -740.71273.80 550,707.686,009,691.581,651.59 0.00 56.28 2,100.00 60.40 1,761.09 248.45 -827.47273.80 550,620.906,009,696.741,700.99 0.00 40.88 2,200.00 60.40 1,810.48 254.21 -914.23273.80 550,534.116,009,701.901,750.38 0.00 25.49 2,300.00 60.40 1,859.87 259.97 -1,000.99273.80 550,447.326,009,707.071,799.77 0.00 10.09 2,400.00 60.40 1,909.27 265.74 -1,087.74273.80 550,360.536,009,712.231,849.17 0.00 -5.31 2,500.00 60.40 1,958.66 271.50 -1,174.50273.80 550,273.756,009,717.391,898.56 0.00 -20.70 2,600.00 60.40 2,008.06 277.26 -1,261.26273.80 550,186.966,009,722.561,947.96 0.00 -36.10 2,700.00 60.40 2,057.45 283.02 -1,348.02273.80 550,100.176,009,727.721,997.35 0.00 -51.50 2,800.00 60.40 2,106.85 288.78 -1,434.78273.80 550,013.386,009,732.882,046.75 0.00 -66.90 2,900.00 60.40 2,156.24 294.55 -1,521.54273.80 549,926.606,009,738.052,096.14 0.00 -82.29 3,000.00 60.40 2,205.63 300.31 -1,608.29273.80 549,839.816,009,743.212,145.53 0.00 -97.69 3,100.00 60.40 2,255.03 306.07 -1,695.05273.80 549,753.026,009,748.372,194.93 0.00 -113.09 3,200.00 60.40 2,304.42 311.83 -1,781.81273.80 549,666.236,009,753.542,244.32 0.00 -128.49 3,300.00 60.40 2,353.82 317.60 -1,868.57273.80 549,579.456,009,758.702,293.72 0.00 -143.88 3,400.00 60.40 2,403.21 323.36 -1,955.33273.80 549,492.666,009,763.862,343.11 0.00 -159.28 3,500.00 60.40 2,452.60 329.12 -2,042.09273.80 549,405.876,009,769.032,392.50 0.00 -174.68 3,600.00 60.40 2,502.00 334.88 -2,128.84273.80 549,319.086,009,774.192,441.90 0.00 -190.08 3,700.00 60.40 2,551.39 340.65 -2,215.60273.80 549,232.306,009,779.352,491.29 0.00 -205.47 7/20/2020 5:09:27PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 2,540.69 Vert Section 3,800.00 60.40 2,600.79 346.41 -2,302.36273.80 549,145.516,009,784.522,540.69 0.00 -220.87 3,900.00 60.40 2,650.18 352.17 -2,389.12273.80 549,058.726,009,789.682,590.08 0.00 -236.27 4,000.00 60.40 2,699.58 357.93 -2,475.88273.80 548,971.936,009,794.842,639.48 0.00 -251.67 4,096.22 60.40 2,747.10 363.48 -2,559.36273.80 548,888.436,009,799.812,687.00 0.00 -266.48 Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD 4,100.00 60.41 2,748.97 363.70 -2,562.64273.97 548,885.156,009,800.012,688.87 4.01 -267.06 4,200.00 60.87 2,798.01 373.20 -2,649.24278.53 548,798.486,009,808.912,737.91 4.00 -278.80 4,286.95 61.40 2,840.00 387.07 -2,724.09282.46 548,723.556,009,822.272,779.90 4.00 -283.44 End Dir : 4286.95' MD, 2840' TVD 4,300.00 61.40 2,846.24 389.54 -2,735.28282.46 548,712.346,009,824.662,786.14 0.00 -283.75 4,400.00 61.40 2,894.11 408.49 -2,821.01282.46 548,626.496,009,843.012,834.01 0.00 -286.11 4,500.00 61.40 2,941.98 427.43 -2,906.74282.46 548,540.646,009,861.352,881.88 0.00 -288.47 4,600.00 61.40 2,989.85 446.37 -2,992.47282.46 548,454.796,009,879.702,929.75 0.00 -290.84 4,700.00 61.40 3,037.72 465.31 -3,078.20282.46 548,368.946,009,898.052,977.62 0.00 -293.20 4,800.00 61.40 3,085.59 484.25 -3,163.93282.46 548,283.096,009,916.403,025.49 0.00 -295.56 4,900.00 61.40 3,133.46 503.19 -3,249.66282.46 548,197.246,009,934.743,073.36 0.00 -297.92 5,000.00 61.40 3,181.33 522.13 -3,335.39282.46 548,111.396,009,953.093,121.23 0.00 -300.28 5,108.31 61.40 3,233.18 542.65 -3,428.25282.46 548,018.406,009,972.963,173.08 0.00 -302.84 Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD 5,200.00 61.67 3,276.90 563.23 -3,506.15287.14 547,940.376,009,993.013,216.80 4.50 -301.71 5,300.00 62.14 3,324.03 592.93 -3,589.17292.22 547,857.166,010,022.133,263.93 4.50 -292.98 5,400.00 62.79 3,370.28 630.02 -3,669.67297.24 547,776.416,010,058.663,310.18 4.50 -276.47 5,500.00 63.63 3,415.37 674.26 -3,747.15302.19 547,698.636,010,102.363,355.27 4.50 -252.29 5,600.00 64.63 3,459.03 725.38 -3,821.15307.07 547,624.296,010,152.963,398.93 4.50 -220.59 5,700.00 65.78 3,500.99 783.07 -3,891.20311.86 547,553.856,010,210.163,440.89 4.50 -181.56 5,800.00 67.09 3,540.98 846.97 -3,956.86316.56 547,487.756,010,273.603,480.88 4.50 -135.44 5,900.00 68.53 3,578.76 916.69 -4,017.74321.16 547,426.406,010,342.893,518.66 4.50 -82.52 6,000.00 70.09 3,614.11 991.79 -4,073.46325.67 547,370.176,010,417.613,554.01 4.50 -23.13 6,100.00 71.77 3,646.79 1,071.83 -4,123.68330.09 547,319.406,010,497.283,586.69 4.50 42.38 6,200.00 73.54 3,676.61 1,156.29 -4,168.08334.42 547,274.426,010,581.433,616.51 4.50 113.59 6,300.00 75.41 3,703.39 1,244.66 -4,206.40338.68 547,235.506,010,669.523,643.29 4.50 190.07 6,400.00 77.34 3,726.96 1,336.40 -4,238.39342.86 547,202.886,010,761.033,666.86 4.50 271.34 6,500.00 79.34 3,747.17 1,430.94 -4,263.86346.97 547,176.766,010,855.383,687.07 4.50 356.91 6,600.00 81.40 3,763.90 1,527.69 -4,282.65351.03 547,157.316,010,952.003,703.80 4.50 446.25 6,700.00 83.50 3,777.05 1,626.07 -4,294.65355.05 547,144.636,011,050.283,716.95 4.50 538.80 6,723.80 84.00 3,779.64 1,649.66 -4,296.50356.00 547,142.626,011,073.853,719.54 4.50 561.24 End Dir : 6723.8' MD, 3779.64' TVD 6,800.00 84.00 3,787.60 1,725.26 -4,301.78356.00 547,136.816,011,149.403,727.50 0.00 633.31 6,823.80 84.00 3,790.09 1,748.87 -4,303.44356.00 547,135.006,011,173.003,729.99 0.00 655.82 Start Dir 4º/100' : 6823.8' MD, 3790.09'TVD 6,823.91 84.00 3,790.10 1,748.98 -4,303.44356.00 547,134.996,011,173.113,730.00 0.00 655.93 9 5/8" x 12 1/4" 6,900.00 85.98 3,796.75 1,824.67 -4,307.19358.33 547,130.726,011,248.773,736.65 4.01 728.47 7,000.00 88.58 3,801.49 1,924.54 -4,307.451.37 547,129.776,011,348.633,741.39 4.00 825.31 7/20/2020 5:09:27PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 3,741.93 Vert Section 7,030.17 89.37 3,802.03 1,954.69 -4,306.492.28 547,130.526,011,378.783,741.93 4.00 854.79 End Dir : 7030.17' MD, 3802.03' TVD 7,100.00 89.37 3,802.80 2,024.46 -4,303.712.28 547,132.826,011,448.563,742.70 0.00 923.16 7,200.00 89.37 3,803.90 2,124.38 -4,299.732.28 547,136.116,011,548.493,743.80 0.00 1,021.07 7,300.00 89.37 3,805.00 2,224.29 -4,295.752.28 547,139.416,011,648.423,744.90 0.00 1,118.98 7,400.00 89.37 3,806.09 2,324.20 -4,291.772.28 547,142.706,011,748.353,745.99 0.00 1,216.89 7,500.00 89.37 3,807.19 2,424.12 -4,287.792.28 547,145.996,011,848.283,747.09 0.00 1,314.80 7,600.00 89.37 3,808.29 2,524.03 -4,283.812.28 547,149.286,011,948.213,748.19 0.00 1,412.71 7,700.00 89.37 3,809.39 2,623.95 -4,279.832.28 547,152.576,012,048.143,749.29 0.00 1,510.62 7,800.00 89.37 3,810.49 2,723.86 -4,275.842.28 547,155.866,012,148.073,750.39 0.00 1,608.53 7,900.00 89.37 3,811.59 2,823.78 -4,271.862.28 547,159.156,012,248.003,751.49 0.00 1,706.44 8,000.00 89.37 3,812.69 2,923.69 -4,267.882.28 547,162.446,012,347.933,752.59 0.00 1,804.35 8,100.00 89.37 3,813.79 3,023.61 -4,263.902.28 547,165.746,012,447.863,753.69 0.00 1,902.26 8,200.00 89.37 3,814.89 3,123.52 -4,259.922.28 547,169.036,012,547.793,754.79 0.00 2,000.17 8,300.00 89.37 3,815.98 3,223.44 -4,255.942.28 547,172.326,012,647.723,755.88 0.00 2,098.08 8,400.00 89.37 3,817.08 3,323.35 -4,251.962.28 547,175.616,012,747.653,756.98 0.00 2,195.99 8,500.00 89.37 3,818.18 3,423.27 -4,247.982.28 547,178.906,012,847.583,758.08 0.00 2,293.90 8,600.00 89.37 3,819.28 3,523.18 -4,244.002.28 547,182.196,012,947.513,759.18 0.00 2,391.81 8,700.00 89.37 3,820.38 3,623.10 -4,240.022.28 547,185.486,013,047.443,760.28 0.00 2,489.72 8,800.00 89.37 3,821.48 3,723.01 -4,236.032.28 547,188.786,013,147.373,761.38 0.00 2,587.63 8,900.00 89.37 3,822.58 3,822.92 -4,232.052.28 547,192.076,013,247.303,762.48 0.00 2,685.54 9,000.00 89.37 3,823.68 3,922.84 -4,228.072.28 547,195.366,013,347.233,763.58 0.00 2,783.45 9,100.00 89.37 3,824.77 4,022.75 -4,224.092.28 547,198.656,013,447.163,764.67 0.00 2,881.36 9,200.00 89.37 3,825.87 4,122.67 -4,220.112.28 547,201.946,013,547.093,765.77 0.00 2,979.27 9,300.00 89.37 3,826.97 4,222.58 -4,216.132.28 547,205.236,013,647.023,766.87 0.00 3,077.18 9,400.00 89.37 3,828.07 4,322.50 -4,212.152.28 547,208.526,013,746.953,767.97 0.00 3,175.09 9,501.59 89.37 3,829.19 4,424.00 -4,208.102.28 547,211.876,013,848.473,769.09 0.00 3,274.56 Start Dir 3º/100' : 9501.59' MD, 3829.19'TVD 9,592.29 89.49 3,830.09 4,514.50 -4,202.355.00 547,217.006,013,939.003,769.99 3.00 3,363.76 9,600.00 89.49 3,830.16 4,522.18 -4,201.665.23 547,217.636,013,946.693,770.06 3.00 3,371.38 9,700.00 89.49 3,831.05 4,621.48 -4,189.948.23 547,228.676,014,046.053,770.95 3.00 3,470.56 9,800.00 89.49 3,831.94 4,720.03 -4,173.0411.23 547,244.896,014,144.703,771.84 3.00 3,570.27 9,893.67 89.50 3,832.76 4,811.41 -4,152.5514.04 547,264.746,014,236.223,772.66 3.00 3,663.90 End Dir : 9893.67' MD, 3832.76' TVD 9,900.00 89.50 3,832.82 4,817.55 -4,151.0114.04 547,266.246,014,242.373,772.72 0.00 3,670.23 10,000.00 89.50 3,833.70 4,914.56 -4,126.7514.04 547,289.836,014,339.533,773.60 0.00 3,770.23 10,100.00 89.50 3,834.58 5,011.57 -4,102.4914.04 547,313.426,014,436.703,774.48 0.00 3,870.22 10,200.00 89.50 3,835.46 5,108.58 -4,078.2314.04 547,337.016,014,533.863,775.36 0.00 3,970.22 10,300.00 89.50 3,836.34 5,205.59 -4,053.9714.04 547,360.606,014,631.023,776.24 0.00 4,070.22 10,400.00 89.50 3,837.22 5,302.60 -4,029.7014.04 547,384.196,014,728.193,777.12 0.00 4,170.21 10,500.00 89.50 3,838.10 5,399.60 -4,005.4414.04 547,407.786,014,825.353,778.00 0.00 4,270.21 10,600.00 89.50 3,838.98 5,496.61 -3,981.1814.04 547,431.376,014,922.523,778.88 0.00 4,370.20 10,700.00 89.50 3,839.86 5,593.62 -3,956.9214.04 547,454.966,015,019.683,779.76 0.00 4,470.20 10,800.00 89.50 3,840.74 5,690.63 -3,932.6614.04 547,478.546,015,116.843,780.64 0.00 4,570.20 10,900.00 89.50 3,841.62 5,787.64 -3,908.3914.04 547,502.136,015,214.013,781.52 0.00 4,670.19 7/20/2020 5:09:27PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 3,782.40 Vert Section 11,000.00 89.50 3,842.50 5,884.64 -3,884.1314.04 547,525.726,015,311.173,782.40 0.00 4,770.19 11,100.00 89.50 3,843.38 5,981.65 -3,859.8714.04 547,549.316,015,408.333,783.28 0.00 4,870.19 11,200.00 89.50 3,844.26 6,078.66 -3,835.6114.04 547,572.906,015,505.503,784.16 0.00 4,970.18 11,300.00 89.50 3,845.14 6,175.67 -3,811.3514.04 547,596.496,015,602.663,785.04 0.00 5,070.18 11,400.00 89.50 3,846.02 6,272.68 -3,787.0814.04 547,620.086,015,699.833,785.92 0.00 5,170.17 11,500.00 89.50 3,846.91 6,369.69 -3,762.8214.04 547,643.676,015,796.993,786.81 0.00 5,270.17 11,600.00 89.50 3,847.79 6,466.69 -3,738.5614.04 547,667.266,015,894.153,787.69 0.00 5,370.17 11,700.00 89.50 3,848.67 6,563.70 -3,714.3014.04 547,690.856,015,991.323,788.57 0.00 5,470.16 11,800.00 89.50 3,849.55 6,660.71 -3,690.0414.04 547,714.446,016,088.483,789.45 0.00 5,570.16 11,820.90 89.50 3,849.73 6,680.98 -3,684.9714.04 547,719.376,016,108.793,789.63 0.00 5,591.06 Start Dir 3º/100' : 11820.9' MD, 3849.73'TVD 11,844.79 88.78 3,850.09 6,704.16 -3,679.1814.00 547,725.006,016,132.003,789.99 3.00 5,614.94 11,900.00 88.78 3,851.26 6,757.52 -3,665.0515.66 547,738.766,016,185.453,791.16 3.00 5,670.13 11,930.05 88.78 3,851.90 6,786.38 -3,656.7216.56 547,746.896,016,214.373,791.80 3.00 5,700.16 End Dir : 11930.05' MD, 3851.9' TVD 12,000.00 88.78 3,853.39 6,853.42 -3,636.7916.56 547,766.366,016,281.533,793.29 0.00 5,770.02 12,100.00 88.78 3,855.51 6,949.25 -3,608.2916.56 547,794.196,016,377.553,795.41 0.00 5,869.90 12,200.00 88.78 3,857.63 7,045.08 -3,579.8016.56 547,822.016,016,473.563,797.53 0.00 5,969.78 12,300.00 88.78 3,859.75 7,140.91 -3,551.3116.56 547,849.846,016,569.583,799.65 0.00 6,069.65 12,400.00 88.78 3,861.87 7,236.74 -3,522.8116.56 547,877.676,016,665.603,801.77 0.00 6,169.53 12,500.00 88.78 3,863.99 7,332.57 -3,494.3216.56 547,905.506,016,761.613,803.89 0.00 6,269.41 12,600.00 88.78 3,866.12 7,428.40 -3,465.8316.56 547,933.336,016,857.633,806.02 0.00 6,369.29 12,700.00 88.78 3,868.24 7,524.23 -3,437.3416.56 547,961.166,016,953.643,808.14 0.00 6,469.17 12,800.00 88.78 3,870.36 7,620.07 -3,408.8416.56 547,988.996,017,049.663,810.26 0.00 6,569.04 12,900.00 88.78 3,872.48 7,715.90 -3,380.3516.56 548,016.816,017,145.683,812.38 0.00 6,668.92 13,000.00 88.78 3,874.60 7,811.73 -3,351.8616.56 548,044.646,017,241.693,814.50 0.00 6,768.80 13,100.00 88.78 3,876.73 7,907.56 -3,323.3616.56 548,072.476,017,337.713,816.63 0.00 6,868.68 13,200.00 88.78 3,878.85 8,003.39 -3,294.8716.56 548,100.306,017,433.733,818.75 0.00 6,968.55 13,300.00 88.78 3,880.97 8,099.22 -3,266.3816.56 548,128.136,017,529.743,820.87 0.00 7,068.43 13,400.00 88.78 3,883.09 8,195.05 -3,237.8816.56 548,155.966,017,625.763,822.99 0.00 7,168.31 13,500.00 88.78 3,885.21 8,290.89 -3,209.3916.56 548,183.796,017,721.783,825.11 0.00 7,268.19 13,600.00 88.78 3,887.33 8,386.72 -3,180.9016.56 548,211.616,017,817.793,827.23 0.00 7,368.07 13,700.00 88.78 3,889.46 8,482.55 -3,152.4016.56 548,239.446,017,913.813,829.36 0.00 7,467.94 13,800.00 88.78 3,891.58 8,578.38 -3,123.9116.56 548,267.276,018,009.823,831.48 0.00 7,567.82 13,900.00 88.78 3,893.70 8,674.21 -3,095.4216.56 548,295.106,018,105.843,833.60 0.00 7,667.70 14,000.00 88.78 3,895.82 8,770.04 -3,066.9316.56 548,322.936,018,201.863,835.72 0.00 7,767.58 14,100.00 88.78 3,897.94 8,865.87 -3,038.4316.56 548,350.766,018,297.873,837.84 0.00 7,867.46 14,200.00 88.78 3,900.06 8,961.70 -3,009.9416.56 548,378.596,018,393.893,839.96 0.00 7,967.33 14,300.00 88.78 3,902.19 9,057.54 -2,981.4516.56 548,406.416,018,489.913,842.09 0.00 8,067.21 14,400.00 88.78 3,904.31 9,153.37 -2,952.9516.56 548,434.246,018,585.923,844.21 0.00 8,167.09 14,500.00 88.78 3,906.43 9,249.20 -2,924.4616.56 548,462.076,018,681.943,846.33 0.00 8,266.97 14,600.00 88.78 3,908.55 9,345.03 -2,895.9716.56 548,489.906,018,777.953,848.45 0.00 8,366.84 14,700.00 88.78 3,910.67 9,440.86 -2,867.4716.56 548,517.736,018,873.973,850.57 0.00 8,466.72 14,800.00 88.78 3,912.79 9,536.69 -2,838.9816.56 548,545.566,018,969.993,852.69 0.00 8,566.60 14,900.00 88.78 3,914.92 9,632.52 -2,810.4916.56 548,573.386,019,066.003,854.82 0.00 8,666.48 7/20/2020 5:09:27PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i 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 3,856.94 Vert Section 15,000.00 88.78 3,917.04 9,728.36 -2,782.0016.56 548,601.216,019,162.023,856.94 0.00 8,766.36 15,100.00 88.78 3,919.16 9,824.19 -2,753.5016.56 548,629.046,019,258.043,859.06 0.00 8,866.23 15,200.00 88.78 3,921.28 9,920.02 -2,725.0116.56 548,656.876,019,354.053,861.18 0.00 8,966.11 15,300.00 88.78 3,923.40 10,015.85 -2,696.5216.56 548,684.706,019,450.073,863.30 0.00 9,065.99 15,400.00 88.78 3,925.52 10,111.68 -2,668.0216.56 548,712.536,019,546.083,865.42 0.00 9,165.87 15,500.00 88.78 3,927.65 10,207.51 -2,639.5316.56 548,740.366,019,642.103,867.55 0.00 9,265.74 15,600.00 88.78 3,929.77 10,303.34 -2,611.0416.56 548,768.186,019,738.123,869.67 0.00 9,365.62 15,700.00 88.78 3,931.89 10,399.17 -2,582.5416.56 548,796.016,019,834.133,871.79 0.00 9,465.50 15,800.00 88.78 3,934.01 10,495.01 -2,554.0516.56 548,823.846,019,930.153,873.91 0.00 9,565.38 15,850.88 88.78 3,935.09 10,543.76 -2,539.5516.56 548,838.006,019,979.003,874.99 0.00 9,616.19 Total Depth : 15850.88' MD, 3935.09' TVD Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Tar gets Dip Angle (°) Dip Dir. (°) MPI-Gaines Mill wp02 Toe 3,935.09 6,019,979.00 548,838.0010,543.76 -2,539.550.00 0.00 -plan hits target center - Point MPI-Gaines Mill wp02 CP2 3,850.09 6,016,132.00 547,725.006,704.16 -3,679.180.00 0.00 -plan hits target center - Point MPI-Gaines Mill wp02 Heel 3,790.09 6,011,173.00 547,135.001,748.87 -4,303.440.00 0.00 -plan hits target center - Circle (radius 30.00) MPI-Gaines Mill wp02 CP1 3,830.09 6,013,939.00 547,217.004,514.50 -4,202.350.00 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"3,790.106,823.91 9-5/8 12-1/4 4 1/2" x 8 1/2"3,935.0915,850.88 4-1/2 8-1/2 7/20/2020 5:09:27PM 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-39i MPU I-39i Survey Calculation Method:Minimum Curvature MPU I-39 As-built RKB @ 60.10usft Design:MPU I-39i wp08 Database:NORTH US + CANADA MD Reference:MPU I-39 As-built RKB @ 60.10usft North Reference: Well Plan: MPU I-39i True Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 250.00 250.00 0.00 0.00 Start Dir 3º/100' : 250' MD, 250'TVD 550.00 548.77 20.36 -11.76 Start Dir 4º/100' : 550' MD, 548.77'TVD 1,996.22 1,709.82 242.47 -737.43 End Dir : 1996.22' MD, 1709.82' TVD 4,096.22 2,747.10 363.48 -2,559.36 Start Dir 4º/100' : 4096.22' MD, 2747.1'TVD 4,286.95 2,840.00 387.07 -2,724.09 End Dir : 4286.95' MD, 2840' TVD 5,108.31 3,233.18 542.65 -3,428.25 Start Dir 4.5º/100' : 5108.31' MD, 3233.18'TVD 6,723.80 3,779.64 1,649.66 -4,296.50 End Dir : 6723.8' MD, 3779.64' TVD 6,823.80 3,790.09 1,748.87 -4,303.44 Start Dir 4º/100' : 6823.8' MD, 3790.09'TVD 7,030.17 3,802.03 1,954.69 -4,306.49 End Dir : 7030.17' MD, 3802.03' TVD 9,501.59 3,829.19 4,424.00 -4,208.10 Start Dir 3º/100' : 9501.59' MD, 3829.19'TVD 9,893.67 3,832.76 4,811.41 -4,152.55 End Dir : 9893.67' MD, 3832.76' TVD 11,820.90 3,849.73 6,680.98 -3,684.97 Start Dir 3º/100' : 11820.9' MD, 3849.73'TVD 11,930.05 3,851.90 6,786.38 -3,656.72 End Dir : 11930.05' MD, 3851.9' TVD 15,850.88 3,935.09 10,543.76 -2,539.55 Total Depth : 15850.88' MD, 3935.09' TVD 7/20/2020 5:09:27PM COMPASS 5000.15 Build 91E Page 9 20 July, 2020Milne PointM Pt I PadPlan: MPU I-39iMPU I-39iMPU I-39i wp08Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Well Coordinates: 6,009,454.03 N, 551,449.98 E (70° 26' 11.69" N, 149° 34' 49.87" W)Datum Height: MPU I-39 As-built RKB @ 60.10usftScan Range: 26.50 to 6,823.91 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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 6,823.91 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-01 - MPI-01 - MPI-01225.37 26.50 223.80 36.39 143.52526.50Centre Distance Pass - MPI-01 - MPI-01 - MPI-01225.80 176.50 223.64 184.94 104.393176.50Ellipse Separation Pass - MPI-01 - MPI-01 - MPI-01290.66 726.50 284.32 700.00 45.900726.50Clearance Factor Pass - MPI-02 - MPI-02 - MPI-02165.29 253.45 162.57 263.51 60.800253.45Centre Distance Pass - MPI-02 - MPI-02 - MPI-02165.36 276.50 162.48 286.62 57.271276.50Ellipse Separation Pass - MPI-02 - MPI-02 - MPI-02213.14 701.50 206.95 690.88 34.468701.50Clearance Factor Pass - MPI-03 - MPI-03 - MPI-03105.33 26.50 103.76 36.39 67.07826.50Centre Distance Pass - MPI-03 - MPI-03 - MPI-03105.36 51.50 103.72 61.13 64.25751.50Ellipse Separation Pass - MPI-03 - MPI-03 - MPI-03131.30 576.50 126.09 576.58 25.184576.50Clearance Factor Pass - MPI-04 - MPI-04 - MPI-0444.58 26.50 43.28 36.40 34.17126.50Centre Distance Pass - MPI-04 - MPI-04 - MPI-0445.20 251.50 42.61 261.17 17.436251.50Ellipse Separation Pass - MPI-04 - MPI-04 - MPI-0457.14 501.50 52.62 510.32 12.645501.50Clearance Factor Pass - MPI-04 - MPI-04A - MPI-04A44.58 26.50 43.47 36.40 40.09426.50Centre Distance Pass - MPI-04 - MPI-04A - MPI-04A45.20 251.50 42.80 261.17 18.836251.50Ellipse Separation Pass - MPI-04 - MPI-04A - MPI-04A59.71 526.50 55.18 535.09 13.185526.50Clearance Factor Pass - MPI-04 - MPI-04AL1 - MPI-04AL144.58 26.50 43.28 36.40 34.17126.50Centre Distance Pass - MPI-04 - MPI-04AL1 - MPI-04AL145.20 251.50 42.61 261.17 17.436251.50Ellipse Separation Pass - MPI-04 - MPI-04AL1 - MPI-04AL157.14 501.50 52.62 510.32 12.645501.50Clearance Factor Pass - MPI-04 - MPI-04APB1 - MPI-04APB144.58 26.50 43.28 36.40 34.17126.50Centre Distance Pass - MPI-04 - MPI-04APB1 - MPI-04APB145.20 251.50 42.61 261.17 17.436251.50Ellipse Separation Pass - MPI-04 - MPI-04APB1 - MPI-04APB157.14 501.50 52.62 510.32 12.645501.50Clearance Factor Pass - MPI-04 - MPI-04PB1 - MPI-04PB144.58 26.50 43.01 36.40 28.39126.50Centre Distance Pass - MPI-04 - MPI-04PB1 - MPI-04PB145.20 251.50 42.50 261.17 16.730251.50Ellipse Separation Pass - MPI-04 - MPI-04PB1 - MPI-04PB157.14 501.50 52.51 510.32 12.346501.50Clearance Factor Pass - MPI-05 - MPI-05 - MPI-05135.22 252.47 132.91 256.47 58.542252.47Centre Distance Pass - MPI-05 - MPI-05 - MPI-05135.31 276.50 132.87 280.49 55.389276.50Ellipse Separation Pass - MPI-05 - MPI-05 - MPI-05172.20 701.50 167.13 700.18 33.972701.50Clearance Factor Pass - MPI-06 - MPI-06 - MPI-0674.70 258.20 71.97 262.39 27.329258.20Centre Distance Pass - 20 July, 2020-17:10COMPASSPage 2 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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 6,823.91 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-06 - MPI-06 - MPI-0674.75 276.50 71.88 280.70 26.072276.50Ellipse Separation Pass - MPI-06 - MPI-06 - MPI-0693.42 576.50 88.22 578.59 17.971576.50Clearance Factor Pass - MPI-07 - MPI-07 - MPI-0714.80 183.33 12.69 187.23 7.005183.33Centre Distance Pass - MPI-07 - MPI-07 - MPI-0714.92 226.50 12.58 230.32 6.379226.50Ellipse Separation Pass - MPI-07 - MPI-07 - MPI-0716.81 326.50 13.91 330.19 5.794326.50Clearance Factor Pass - MPI-08 - MPI-08 - MPI-0815.61 101.50 13.46 105.24 7.250101.50Ellipse Separation Pass - MPI-08 - MPI-08 - MPI-0818.36 476.50 14.64 479.40 4.934476.50Clearance Factor Pass - MPI-09 - MPI-09 - MPI-09194.46 172.55 192.03 174.70 80.182172.55Centre Distance Pass - MPI-09 - MPI-09 - MPI-09194.79 251.50 191.55 252.00 60.058251.50Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-091,496.86 3,251.50 1,416.74 3,298.03 18.6823,251.50Clearance Factor Pass - MPI-10 - MPI-10 - MPI-10255.00 26.50 253.16 27.75 138.29226.50Centre Distance Pass - MPI-10 - MPI-10 - MPI-10255.09 76.50 253.10 77.86 127.99676.50Ellipse Separation Pass - MPI-10 - MPI-10 - MPI-10521.69 4,126.50 338.48 4,574.44 2.8484,126.50Clearance Factor Pass - MPI-11 - MPI-11 - MPI-1142.16 425.18 38.93 427.30 13.078425.18Centre Distance Pass - MPI-11 - MPI-11 - MPI-1142.31 451.50 38.92 453.13 12.488451.50Ellipse Separation Pass - MPI-11 - MPI-11 - MPI-11718.92 3,801.50 574.37 3,870.02 4.9743,801.50Clearance Factor Pass - MPI-11 - MPI-11L1 - MPI-11L142.16 425.18 38.93 427.30 13.078425.18Centre Distance Pass - MPI-11 - MPI-11L1 - MPI-11L142.31 451.50 38.92 453.13 12.488451.50Ellipse Separation Pass - MPI-11 - MPI-11L1 - MPI-11L1718.92 3,801.50 574.37 3,870.02 4.9743,801.50Clearance Factor Pass - MPI-12 - MPI-12 - MPI-1256.63 722.30 51.63 721.55 11.329722.30Centre Distance Pass - MPI-12 - MPI-12 - MPI-12177.403,801.5018.354,124.331.1153,801.50Ellipse SeparationPass - MPI-12 - MPI-12 - MPI-12178.803,826.5018.384,149.991.1153,826.50Clearance FactorPass - MPI-12 - MPI-12L1 - MPI-12L156.63 722.30 51.63 721.55 11.329722.30Centre Distance Pass - MPI-12 - MPI-12L1 - MPI-12L1177.403,801.5018.354,124.331.1153,801.50Ellipse SeparationPass - MPI-12 - MPI-12L1 - MPI-12L1178.803,826.5018.384,149.991.1153,826.50Clearance FactorPass - MPI-12 - MPI-12PB1 - MPI-12PB156.63 722.30 51.63 721.55 11.329722.30Centre Distance Pass - MPI-12 - MPI-12PB1 - MPI-12PB1177.403,801.5018.044,124.331.1133,801.50Ellipse SeparationPass - MPI-12 - MPI-12PB1 - MPI-12PB1178.803,826.5018.074,149.991.1123,826.50Clearance FactorPass - MPI-13 - MPI-13 - MPI-1397.92 623.74 93.66 617.87 22.987623.74Centre Distance Pass - MPI-13 - MPI-13 - MPI-1398.13 676.50 93.50 668.64 21.220676.50Ellipse Separation Pass - 20 July, 2020-17:10COMPASSPage 3 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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 6,823.91 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-13 - MPI-13 - MPI-13360.50 3,576.50 225.22 3,680.09 2.6653,576.50Clearance Factor Pass - MPI-14 - MPI-14 - MPI-1494.38 1,076.08 86.54 1,046.79 12.0451,076.08Centre Distance Pass - MPI-14 - MPI-14 - MPI-14238.594,251.5071.904,293.291.4314,251.50Ellipse SeparationPass - MPI-14 - MPI-14 - MPI-14246.384,301.5073.154,341.581.4224,301.50Clearance FactorPass - MPI-14 - MPI-14L1 - MPI-14L194.38 1,076.08 86.54 1,046.79 12.0451,076.08Centre Distance Pass - MPI-14 - MPI-14L1 - MPI-14L1238.594,251.5072.044,293.291.4324,251.50Ellipse SeparationPass - MPI-14 - MPI-14L1 - MPI-14L1246.384,301.5073.284,341.581.4234,301.50Clearance FactorPass - MPI-14 - MPI-14L2 - MPI-14L294.38 1,076.08 86.54 1,046.79 12.0451,076.08Centre Distance Pass - MPI-14 - MPI-14L2 - MPI-14L2238.594,251.5072.064,293.291.4334,251.50Ellipse SeparationPass - MPI-14 - MPI-14L2 - MPI-14L2246.384,301.5073.304,341.581.4244,301.50Clearance FactorPass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB194.38 1,076.08 86.54 1,046.79 12.0451,076.08Centre Distance Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1238.594,251.5071.774,293.291.4304,251.50Ellipse SeparationPass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1246.384,301.5073.024,341.581.4214,301.50Clearance FactorPass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB294.38 1,076.08 86.54 1,046.79 12.0451,076.08Centre Distance Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2238.594,251.5071.774,293.291.4304,251.50Ellipse SeparationPass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2246.384,301.5073.024,341.581.4214,301.50Clearance FactorPass - MPI-14 - MPI-14PB1 - MPI-14PB194.38 1,076.08 86.54 1,046.79 12.0451,076.08Centre Distance Pass - MPI-14 - MPI-14PB1 - MPI-14PB1238.594,251.5071.904,293.291.4314,251.50Ellipse SeparationPass - MPI-14 - MPI-14PB1 - MPI-14PB1246.384,301.5073.154,341.581.4224,301.50Clearance FactorPass - MPI-14 - MPI-14PB2 - MPI-14PB294.38 1,076.08 86.54 1,046.79 12.0451,076.08Centre Distance Pass - MPI-14 - MPI-14PB2 - MPI-14PB2238.594,251.5071.904,293.291.4314,251.50Ellipse SeparationPass - MPI-14 - MPI-14PB2 - MPI-14PB2246.384,301.5073.154,341.581.4224,301.50Clearance FactorPass - MPI-17 - MPI-17 - MPI-17324.76 5,689.36 217.36 7,404.70 3.0245,689.36Centre Distance Pass - MPI-17 - MPI-17 - MPI-17377.69 5,926.50 168.95 7,571.09 1.8095,926.50Ellipse Separation Pass - MPI-17 - MPI-17 - MPI-17414.02 6,001.50 177.06 7,625.09 1.7476,001.50Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L1339.94 26.50 338.10 33.75 184.35726.50Centre Distance Pass - MPI-17 - MPI-17L1 - MPI-17L1504.97 6,051.50 332.07 7,612.14 2.9216,051.50Ellipse Separation Pass - MPI-17 - MPI-17L1 - MPI-17L1593.77 6,226.50 368.63 7,700.12 2.6376,226.50Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1339.94 26.50 338.10 33.75 184.35726.50Centre Distance Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1517.36 6,126.50 303.87 7,712.04 2.4236,126.50Ellipse SeparationPass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB1555.13 6,201.50 313.67 7,746.00 2.2996,201.50Clearance Factor Pass - 20 July, 2020-17:10COMPASSPage 4 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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 6,823.91 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPI-17 - MPI-17L2 - MPI-17L2339.94 26.50 338.10 33.75 184.35726.50Centre Distance Pass - MPI-17 - MPI-17L2 - MPI-17L2520.44 5,976.50 325.19 7,592.24 2.6655,976.50Ellipse Separation Pass - MPI-17 - MPI-17L2 - MPI-17L2597.73 6,151.50 350.74 7,726.22 2.4206,151.50Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1400.17 26.50 398.33 34.30 217.02126.50Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1585.50 1,276.50 574.72 1,316.35 54.3301,276.50Clearance Factor Pass - MPU I-36 - MPU I-36 - MPU I-36239.02 256.33 236.83 256.85 109.003256.33Centre Distance Pass - MPU I-36 - MPU I-36 - MPU I-36239.06 276.50 236.79 277.50 105.129276.50Ellipse Separation Pass - MPU I-36 - MPU I-36 - MPU I-361,173.28 2,776.50 1,149.99 2,901.24 50.3652,776.50Clearance Factor Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1239.02 256.33 236.61 256.85 99.330256.33Centre Distance Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB1239.06 276.50 236.57 277.50 96.104276.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB1 - MPU I-36PB11,173.28 2,776.50 1,149.77 2,901.24 49.9072,776.50Clearance Factor Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2239.02 256.33 236.61 256.85 99.330256.33Centre Distance Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB2239.06 276.50 236.57 277.50 96.104276.50Ellipse Separation Pass - MPU I-36 - MPU I-36PB2 - MPU I-36PB21,173.28 2,776.50 1,149.79 2,901.24 49.9412,776.50Clearance Factor Pass - MPU I-37i - MPU I-37i - MPU I-37i119.36 274.15 117.06 275.32 51.943274.15Centre Distance Pass - MPU I-37i - MPU I-37i - MPU I-37i119.45 301.50 117.03 302.84 49.487301.50Ellipse Separation Pass - MPU I-37i - MPU I-37i - MPU I-37i1,272.15 4,801.50 1,224.40 4,639.48 26.6384,801.50Clearance Factor Pass - MPU I-37i - MPU I-37PB1 - MPU I-37PB1119.36 274.15 116.85 275.32 47.526274.15Centre Distance Pass - MPU I-37i - MPU I-37PB1 - MPU I-37PB1119.45 301.50 116.82 302.84 45.464301.50Ellipse Separation Pass - MPU I-37i - MPU I-37PB1 - MPU I-37PB11,272.15 4,801.50 1,224.18 4,639.48 26.5174,801.50Clearance Factor Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03210.14 226.50 207.78 227.40 88.999226.50Centre Distance Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp03210.24 276.50 207.68 277.40 82.097276.50Ellipse Separation Pass - Plan: MPU I-22 - MPU I-22 - MPU I-22 wp031,212.67 3,076.50 1,178.24 3,225.33 35.2183,076.50Clearance Factor Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp03150.41 226.50 148.05 227.40 63.702226.50Centre Distance Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp03150.51 276.50 147.95 277.40 58.772276.50Ellipse Separation Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,479.16 5,026.50 1,420.24 4,900.00 25.1035,026.50Clearance Factor Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp0289.73 568.96 85.69 578.31 22.187568.96Centre Distance Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp0289.82 601.50 85.59 611.95 21.233601.50Ellipse Separation Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02991.67 6,551.50 915.62 6,346.33 13.0396,551.50Clearance Factor Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp0441.33 1,060.45 34.87 1,052.55 6.3951,060.45Centre Distance Pass - 20 July, 2020-17:10COMPASSPage 5 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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 6,823.91 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-25i - MPU I-25i - MPU I-25i wp0441.35 1,076.50 34.83 1,068.41 6.3421,076.50Ellipse Separation Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp04220.51 6,823.91 169.11 6,795.23 4.2916,823.91Clearance Factor Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06118.21 401.50 115.22 397.47 39.447401.50Centre Distance Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06118.29 426.50 115.17 420.95 37.841426.50Ellipse Separation Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06492.15 5,776.50 357.44 5,603.61 3.6535,776.50Clearance Factor Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp04180.16 257.74 177.68 259.03 72.511257.74Centre Distance Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp04180.36 351.50 177.45 356.82 61.995351.50Ellipse Separation Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp04623.32 2,951.50 582.82 3,242.10 15.3912,951.50Clearance Factor Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp0329.72 226.50 27.36 227.40 12.587226.50Centre Distance Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp0329.72 251.50 27.26 252.40 12.088251.50Ellipse Separation Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp03522.67 4,276.50 426.65 4,368.16 5.4434,276.50Clearance Factor Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp0580.89 563.94 76.94 559.57 20.489563.94Centre Distance Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp0580.94 576.50 76.93 571.31 20.172576.50Ellipse Separation Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp05280.29 5,251.50 132.78 5,321.13 1.9005,251.50Clearance Factor Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05154.52 333.96 151.72 331.17 55.055333.96Centre Distance Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05154.55 351.50 151.67 347.51 53.563351.50Ellipse Separation Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05716.37 5,776.50 583.88 5,517.42 5.4075,776.50Clearance Factor Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp0929.59 367.41 26.62 366.60 9.976367.41Centre Distance Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp0929.60 376.50 26.60 375.56 9.840376.50Ellipse Separation Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09726.07 4,526.50 614.09 4,514.41 6.4844,526.50Clearance Factor Pass - Rig: MPU I-38 - MPU I-38 - MPU I-3859.90 26.50 57.99 26.70 31.33926.50Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38 - MPU I-3879.13 101.50 75.18 50.00 20.031101.50Clearance Factor Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38 wp0959.90 226.50 57.54 226.70 25.385226.50Centre Distance Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38 wp0960.00 276.50 57.44 276.70 23.444276.50Ellipse Separation Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38 wp09612.16 3,901.50 541.67 4,191.16 8.6853,901.50Clearance Factor Pass - M Pt J Pad20 July, 2020-17:10COMPASSPage 6 of 9 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 900.00 MPU I-39i wp08 3_Gyro-GC_Csg900.00 6,823.91 MPU I-39i wp08 3_MWD+IFR2+MS+Sag6,823.91 15,850.88 MPU I-39i wp08 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.20 July, 2020-17:10COMPASSPage 7 of 9 0.001.002.003.004.00Separation Factor0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPI-12No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.WELL DETAILS:Plan: MPU I-39i NAD 1927 (NADCON CONUS)Alaska Zone 04+N/-S + Longitude0.0033.60E/-WNorthingEastingLatittude0.006009454.03551449.98 70° 26' 11.686 N149° 34' 49.869 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-39i, True NorthVertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usftMeasured Depth Reference:MPU I-39 As-built RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-07-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 900.00 MPU I-39i wp08 (MPU I-39i) 3_Gyro-GC_Csg900.00 6823.91 MPU I-39i wp08 (MPU I-39i) 3_MWD+IFR2+MS+Sag6823.91 15850.88 MPU I-39i wp08 (MPU I-39i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650Measured Depth (700 usft/in)MPI-02MPI-03MPI-04MPI-05MPI-06MPI-07MPI-08MPI-11MPI-14MPU I-37iMPU I-23i wp03MPU I-24 wp02MPU I-25i wp04MPU I-25i wp04MPU I-26 wp06MPU I-31 wp03MPU I-32i wp05MPU I-33 wp05MPU I-40 wp09MPU I-38MPU I-38 wp09NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 15850.88Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-39iWellbore: MPU I-39iPlan: MPU I-39i wp08Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3790.10 3730.00 6823.91 9-5/8 9 5/8" x 12 1/4"3935.09 3874.99 15850.88 4-1/2 4 1/2" x 8 1/2" 20 July, 2020Milne PointM Pt I PadPlan: MPU I-39iMPU I-39iMPU I-39i wp08Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Well Coordinates: 6,009,454.03 N, 551,449.98 E (70° 26' 11.69" N, 149° 34' 49.87" W)Datum Height: MPU I-39 As-built RKB @ 60.10usftScan Range: 6,823.91 to 15,850.88 usft. Measured Depth.Geodetic Scale Factor AppliedVersion: 5000.15 Build: 91EScan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usftNO GLOBAL FILTER: Using user defined selection & filtering criteriaScan Type:Scan Type:25.00 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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: 6,823.91 to 15,850.88 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningM Pt I PadMPI-09 - MPI-09 - MPI-091,337.01 8,723.91 1,071.90 7,675.24 5.0438,723.91Clearance Factor Pass - MPI-09 - MPI-09 - MPI-091,132.24 9,423.91 958.73 8,164.30 6.5259,423.91Ellipse Separation Pass - MPI-09 - MPI-09 - MPI-091,092.26 9,908.96 989.72 8,467.84 10.6529,908.96Centre Distance Pass - MPI-12 - MPI-12 - MPI-121,322.69 6,823.91 1,072.37 6,464.93 5.2846,823.91Clearance Factor Pass - MPI-12 - MPI-12L1 - MPI-12L11,322.69 6,823.91 1,072.37 6,464.93 5.2846,823.91Clearance Factor Pass - MPI-12 - MPI-12PB1 - MPI-12PB11,322.69 6,823.91 1,071.92 6,464.93 5.2756,823.91Clearance Factor Pass - MPI-14 - MPI-14 - MPI-14304.46 6,823.91 188.98 7,120.19 2.6376,823.91Clearance Factor Pass - MPI-14 - MPI-14L1 - MPI-14L1304.46 6,823.91 189.11 7,120.19 2.6396,823.91Clearance Factor Pass - MPI-14 - MPI-14L2 - MPI-14L2282.65 6,823.91 198.74 7,167.72 3.3686,823.91Ellipse Separation Pass - MPI-14 - MPI-14L2 - MPI-14L2792.44 9,648.91 513.94 9,768.00 2.8459,648.91Clearance Factor Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1292.85 6,823.91 190.22 7,139.00 2.8546,823.91Ellipse Separation Pass - MPI-14 - MPI-14L2PB1 - MPI-14L2PB1511.59 7,298.91 246.36 7,391.00 1.9297,298.91Clearance Factor Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2282.65 6,823.91 198.46 7,167.72 3.3576,823.91Ellipse Separation Pass - MPI-14 - MPI-14L2PB2 - MPI-14L2PB2823.52 9,523.91 532.48 9,594.00 2.8309,523.91Clearance Factor Pass - MPI-14 - MPI-14PB1 - MPI-14PB1304.46 6,823.91 188.98 7,120.19 2.6376,823.91Clearance Factor Pass - MPI-14 - MPI-14PB2 - MPI-14PB2304.46 6,823.91 188.98 7,120.19 2.6376,823.91Clearance Factor Pass - MPI-17 - MPI-17 - MPI-171,082.79 6,823.91 785.36 8,089.37 3.6406,823.91Clearance Factor Pass - MPI-17 - MPI-17L1 - MPI-17L11,087.44 6,823.91 809.85 7,918.02 3.9176,823.91Clearance Factor Pass - MPI-17 - MPI-17L1PB1 - MPI-17L1PB11,088.00 6,823.91 806.61 7,746.00 3.8666,823.91Clearance Factor Pass - MPI-17 - MPI-17L2 - MPI-17L21,135.02 6,823.91 830.48 8,001.81 3.7276,823.91Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1493.52 13,273.91 253.14 12,225.00 2.05313,273.91Clearance Factor Pass - MPI-19 - MPI-19L1 - MPI-19L1442.88 13,398.91 236.86 12,225.00 2.15013,398.91Ellipse Separation Pass - MPI-19 - MPI-19L1 - MPI-19L1424.23 13,526.09 249.98 12,225.00 2.43513,526.09Centre Distance Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,401.92 15,423.91 1,166.57 13,972.93 5.95715,423.91Clearance Factor Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,399.18 15,473.91 1,165.08 13,977.74 5.97715,473.91Ellipse Separation Pass - Plan: MPU I-23i - MPU I-23i - MPU I-23i wp031,398.23 15,525.70 1,165.86 13,977.74 6.01715,525.70Centre Distance Pass - Plan: MPU I-24 - MPU I-24 - MPU I-24 wp02662.62 15,850.88 431.66 15,251.07 2.86915,850.88Clearance Factor Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp04173.83 9,382.99 121.44 9,355.71 3.3189,382.99Centre Distance Pass - 20 July, 2020-17:11COMPASSPage 2 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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: 6,823.91 to 15,850.88 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningPlan: MPU I-25i - MPU I-25i - MPU I-25i wp04174.37 9,448.91 121.07 9,418.84 3.2719,448.91Ellipse Separation Pass - Plan: MPU I-25i - MPU I-25i - MPU I-25i wp04217.12 15,850.88 122.08 15,808.68 2.28415,850.88Clearance Factor Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06669.02 15,684.56 444.75 16,628.00 2.98315,684.56Centre Distance Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06672.10 15,748.91 441.37 16,628.00 2.91315,748.91Ellipse Separation Pass - Plan: MPU I-26 - MPU I-26 - MPU I-26 wp06689.38 15,850.88 449.02 16,628.00 2.86815,850.88Clearance Factor Pass - Plan: MPU I-30i - MPU I-30i - MPU I-30i wp041,361.49 15,850.88 1,115.56 14,821.47 5.53615,850.88Clearance Factor Pass - Plan: MPU I-31 - MPU I-31 - MPU I-31 wp03653.16 15,850.88 414.14 15,671.44 2.73315,850.88Clearance Factor Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp05161.72 9,866.17 100.60 10,284.54 2.6469,866.17Centre Distance Pass - Plan: MPU I-32i - MPU I-32i - MPU I-32i wp05183.67 15,850.88 83.31 16,273.64 1.83015,850.88Clearance Factor Pass - Plan: MPU I-33 - MPU I-33 - MPU I-33 wp05782.78 15,850.88 546.34 17,069.95 3.31115,850.88Clearance Factor Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09840.12 15,592.76 600.28 17,341.21 3.50315,592.76Centre Distance Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09841.99 15,648.91 597.86 17,341.21 3.44915,648.91Ellipse Separation Pass - Plan: MPU I-40 - MPU I-40 - MPU I-40 wp09859.43 15,773.91 606.50 17,341.21 3.39815,773.91Clearance Factor Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38 wp09838.96 13,237.19 661.71 12,636.08 4.73313,237.19Centre Distance Pass - Rig: MPU I-38 - MPU I-38 - MPU I-38 wp09849.34 15,850.88 605.81 15,239.32 3.48815,850.88Clearance Factor Pass - M Pt J PadMPJ-08 - MPJ-08A - MPJ-08A213.01 13,370.21 149.39 7,843.96 3.34813,370.21Centre Distance Pass - MPJ-08 - MPJ-08A - MPJ-08A219.67 13,423.91 148.55 7,842.88 3.08913,423.91Ellipse Separation Pass - MPJ-08 - MPJ-08A - MPJ-08A391.63 13,698.91 193.96 7,836.98 1.98113,698.91Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-091,498.78 13,798.91 1,321.32 6,682.61 8.44613,798.91Clearance Factor Pass - MPJ-09 - MPJ-09 - MPJ-091,465.13 14,148.91 1,303.42 7,083.98 9.06014,148.91Ellipse Separation Pass - MPJ-09 - MPJ-09 - MPJ-091,457.36 14,360.79 1,312.15 7,244.69 10.03614,360.79Centre Distance Pass - MPJ-09 - MPJ-09A - MPJ-09A172.89 12,993.48 111.75 7,367.57 2.82812,993.48Centre Distance Pass - MPJ-09 - MPJ-09A - MPJ-09A175.15 13,023.91 110.67 7,355.28 2.71613,023.91Ellipse Separation Pass - MPJ-09 - MPJ-09A - MPJ-09A292.07 13,248.91 148.68 7,266.30 2.03713,248.91Clearance Factor Pass - MPJ-15 - MPJ-15 - MPJ-151,351.14 15,398.91 1,032.49 7,145.00 4.24015,398.91Clearance Factor Pass - MPJ-15 - MPJ-15 - MPJ-151,298.28 15,648.91 1,002.76 7,145.00 4.39315,648.91Ellipse Separation Pass - MPJ-15 - MPJ-15 - MPJ-151,288.98 15,804.00 1,012.57 7,145.00 4.66315,804.00Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17381.21 11,023.91 163.57 6,413.13 1.75211,023.91Clearance Factor Pass - 20 July, 2020-17:11COMPASSPage 3 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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: 6,823.91 to 15,850.88 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-17 - MPJ-17 - MPJ-17203.10 11,346.55 118.88 6,418.33 2.41211,346.55Centre Distance Pass - MPJ-17 - MPJ-17 - MPJ-17203.11 11,348.91 118.86 6,418.37 2.41111,348.91Ellipse Separation Pass - MPJ-18 - MPJ-18 - MPJ-1833.5714,623.91-282.147,417.050.10614,623.91Ellipse SeparationFAIL - MPJ-18 - MPJ-18 - MPJ-1813.9314,648.91-170.167,431.090.07614,648.91Clearance FactorFAIL - MPJ-18 - MPJ-18 - MPJ-186.5914,663.79-78.757,439.490.07714,663.79Centre DistanceFAIL - MPJ-19 - MPJ-19 - MPJ-19403.48 12,373.91 258.59 6,678.35 2.78512,373.91Clearance Factor Pass - MPJ-19 - MPJ-19 - MPJ-19286.80 12,623.91 213.65 6,742.01 3.92112,623.91Ellipse Separation Pass - MPJ-19 - MPJ-19 - MPJ-19283.13 12,671.13 215.42 6,754.04 4.18112,671.13Centre Distance Pass - MPJ-20 - MPJ-20 - MPJ-201,028.72 9,573.91 789.28 7,108.17 4.2969,573.91Clearance Factor Pass - MPJ-20 - MPJ-20 - MPJ-20744.94 10,148.91 638.66 6,946.99 7.00910,148.91Ellipse Separation Pass - MPJ-20 - MPJ-20 - MPJ-20730.23 10,301.50 644.87 6,891.14 8.55410,301.50Centre Distance Pass - MPJ-20 - MPJ-20A - MPJ-20A1,234.15 9,373.91 1,017.06 6,857.57 5.6859,373.91Clearance Factor Pass - MPJ-20 - MPJ-20A - MPJ-20A834.25 10,273.91 768.73 6,544.79 12.73210,273.91Ellipse Separation Pass - MPJ-20 - MPJ-20A - MPJ-20A832.07 10,337.22 769.41 6,524.60 13.27810,337.22Centre Distance Pass - MPJ-23 - MPJ-23 - MPJ-231,090.43 10,023.91 850.00 6,420.38 4.53510,023.91Clearance Factor Pass - MPJ-23 - MPJ-23 - MPJ-23724.55 10,773.91 645.55 6,271.45 9.17110,773.91Ellipse Separation Pass - MPJ-23 - MPJ-23 - MPJ-23718.87 10,867.07 647.42 6,249.41 10.06010,867.07Centre Distance Pass - MPJ-23 - MPJ-23A - MPJ-23A1,090.43 10,023.91 841.93 6,427.88 4.38810,023.91Clearance Factor Pass - MPJ-23 - MPJ-23A - MPJ-23A724.55 10,773.91 645.20 6,278.95 9.13010,773.91Ellipse Separation Pass - MPJ-23 - MPJ-23A - MPJ-23A718.87 10,867.07 647.35 6,256.91 10.05110,867.07Centre Distance Pass - MPJ-23 - MPJ-23L1 - MPJ-23L11,090.43 10,023.91 850.00 6,420.38 4.53510,023.91Clearance Factor Pass - MPJ-23 - MPJ-23L1 - MPJ-23L1724.55 10,773.91 645.55 6,271.45 9.17110,773.91Ellipse Separation Pass - MPJ-23 - MPJ-23L1 - MPJ-23L1718.87 10,867.07 647.42 6,249.41 10.06010,867.07Centre Distance Pass - MPJ-24 - MPJ-24A - MPJ-24A712.07 12,389.14 634.76 6,142.55 9.21112,389.14Centre Distance Pass - MPJ-24 - MPJ-24A - MPJ-24A712.13 12,398.91 634.69 6,142.68 9.19612,398.91Ellipse Separation Pass - MPJ-24 - MPJ-24A - MPJ-24A1,078.23 13,198.91 833.13 6,161.70 4.39913,198.91Clearance Factor Pass - MPJ-24 - MPJ-24L1 - MPJ-24L1712.07 12,389.14 634.86 6,146.26 9.22312,389.14Centre Distance Pass - MPJ-24 - MPJ-24L1 - MPJ-24L1712.13 12,398.91 634.80 6,146.39 9.20812,398.91Ellipse Separation Pass - MPJ-24 - MPJ-24L1 - MPJ-24L11,078.23 13,198.91 836.48 6,165.41 4.46013,198.91Clearance Factor Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB1712.07 12,389.14 634.76 6,146.26 9.21112,389.14Centre Distance Pass - 20 July, 2020-17:11COMPASSPage 4 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Comparison 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: 6,823.91 to 15,850.88 usft. Measured Depth. Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference)Reference Design: M Pt I Pad - Plan: MPU I-39i - MPU I-39i - MPU I-39i wp08MeasuredDepth(usft)Summary Based on MinimumSeparation WarningMPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB1712.13 12,398.91 634.69 6,146.39 9.19612,398.91Ellipse Separation Pass - MPJ-24 - MPJ-24L1PB1 - MPJ-24L1PB11,078.23 13,198.91 836.12 6,165.41 4.45313,198.91Clearance Factor Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB2712.07 12,389.14 634.76 6,146.26 9.21112,389.14Centre Distance Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB2712.13 12,398.91 634.69 6,146.39 9.19612,398.91Ellipse Separation Pass - MPJ-24 - MPJ-24L1PB2 - MPJ-24L1PB21,078.23 13,198.91 836.39 6,165.41 4.45813,198.91Clearance Factor Pass - MPJ-24 - MPU J-24 - MPJ-24712.07 12,389.14 634.76 6,146.26 9.21112,389.14Centre Distance Pass - MPJ-24 - MPU J-24 - MPJ-24712.13 12,398.91 634.69 6,146.39 9.19612,398.91Ellipse Separation Pass - MPJ-24 - MPU J-24 - MPJ-241,078.23 13,198.91 836.39 6,165.41 4.45813,198.91Clearance Factor Pass - MPJ-25 - MPJ-25 - MPJ-258.6813,110.16-54.607,448.930.13713,110.16Clearance FactorFAIL - MPJ-25 - MPJ-25 - MPJ-2585.3913,198.91-154.357,473.160.35613,198.91Ellipse SeparationFAIL - MPJ-26 - MPJ-26 - MPJ-262.219,958.26-53.687,059.140.0399,958.26Clearance FactorFAIL - MPJ-26 - MPJ-26 - MPJ-2615.489,973.91-107.397,062.320.1269,973.91Ellipse SeparationFAIL - MPJ-26 - MPJ-26L1 - MPJ-26L1354.88 9,673.91 172.46 7,023.58 1.9459,673.91Clearance Factor Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1175.00 9,973.91 124.95 7,053.79 3.4969,973.91Ellipse Separation Pass - MPJ-26 - MPJ-26L1 - MPJ-26L1174.65 9,985.04 124.99 7,054.69 3.5179,985.04Centre Distance Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2251.07 9,798.91 109.09 6,949.71 1.7689,798.91Clearance Factor Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2120.55 10,023.91 71.14 7,025.14 2.44010,023.91Ellipse Separation Pass - MPJ-26 - MPJ-26L2 - MPJ-26L2119.97 10,036.78 71.38 7,030.18 2.46910,036.78Centre Distance Pass - MPJ-26 - MPJ-26PB1 - MPJ-26PB12.219,958.26-53.837,059.140.0399,958.26Clearance FactorFAIL - MPJ-26 - MPJ-26PB1 - MPJ-26PB115.489,973.91-107.547,062.320.1269,973.91Ellipse SeparationFAIL - MPJ-26 - MPJ-26PB2 - MPJ-26PB22.219,958.26-53.837,059.140.0399,958.26Clearance FactorFAIL - MPJ-26 - MPJ-26PB2 - MPJ-26PB215.489,973.91-107.547,062.320.1269,973.91Ellipse SeparationFAIL - MPJ-27 - MPJ-27 - MPJ-27736.80 11,458.92 676.18 6,396.34 12.15411,458.92Ellipse Separation Pass - MPJ-27 - MPJ-27 - MPJ-271,050.18 12,198.91 896.13 6,391.17 6.81712,198.91Clearance Factor Pass - MPJ-28 - MPJ-28 - MPJ-281,081.21 9,423.91 930.99 6,721.56 7.1989,423.91Clearance Factor Pass - MPJ-28 - MPJ-28 - MPJ-28772.54 10,123.91 713.35 6,631.55 13.05210,123.91Ellipse Separation Pass - MPJ-28 - MPJ-28 - MPJ-28770.97 10,174.27 713.79 6,621.12 13.48410,174.27Centre Distance Pass - 20 July, 2020-17:11COMPASSPage 5 of 8 Milne PointHilcorp Alaska, LLCAnticollision Report for Plan: MPU I-39i - MPU I-39i wp08Survey tool programFrom(usft)To(usft)Survey/Plan Survey Tool26.50 900.00 MPU I-39i wp08 3_Gyro-GC_Csg900.00 6,823.91 MPU I-39i wp08 3_MWD+IFR2+MS+Sag6,823.91 15,850.88 MPU I-39i wp08 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.20 July, 2020-17:11COMPASSPage 6 of 8 0.001.002.003.004.00Separation Factor7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200 15675Measured Depth (950 usft/in)MPI-14L2PB1MPJ-18MPJ-26No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:Plan: MPU I-39i NAD 1927 (NADCON CONUS)Alaska Zone 04+N/-S + Latittude Longitude0.0033.60E/-WNorthingEasting0.006009454.03551449.98 70° 26' 11.686 N149° 34' 49.869 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-39i, True NorthVertical (TVD) Reference:MPU I-39 As-built RKB @ 60.10usftMeasured Depth Reference:MPU I-39 As-built RKB @ 60.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-07-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool26.50 900.00 MPU I-39i wp08 (MPU I-39i) 3_Gyro-GC_Csg900.00 6823.91 MPU I-39i wp08 (MPU I-39i) 3_MWD+IFR2+MS+Sag6823.91 15850.88 MPU I-39i wp08 (MPU I-39i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 14725 15200 15675Measured Depth (950 usft/in)MPJ-26MPJ-26PB1MPJ-26PB2NO GLOBAL FILTER: Using user defined selection & filtering criteria26.50 To 15850.88Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-39iWellbore: MPU I-39iPlan: MPU I-39i wp08Ladder / S.F. 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