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219-070
Surface Casing by Conductor Annulus Fill Coat Corrosion Inhibitor (CI) Applications Well Field - API PTD FTOPInhibitor Corrosion Fill Volume (gal) Final CI Top (ft.) Corrosion Inhibitor Treatment Date E-35 Milne Point 50029236150000 2181520 Surface 22.5 Top of Cond 10/24/2019 E-36 Milne Point 50029236200000 2190050 Surface 15 Top of Cond 10/24/2019 E-38 Milne Point 50029236260000 2190440 Surface 20 Top of Cond 10/24/2019 E-39 Milne Point 50029236400000/60-00 2190960 Surface 20 Top of Cond 10/24/2019 E-40 Milne Point 50029236260000 2190440 Surface 25 Top of Cond 10/25/2019 E-41 Milne Point 50029236220000 2190310 Surface 15 Top of Cond 10/24/2019 E-42 Milne Point 50029236350000/60-00 2190820 Surface 17 Top of Cond 10/25/2019 M-18 Milne Point. 50029236320000 2190700 3 50 Top of Cond 10/26/2019 M-06 Milne Point 50029236460000 2191130 3 30 Top of Cond 10/26/2019 Cement to surface means cement is up to the 4" outlets below the wellhead. From the 4" outlets up to the top of Conductor was filled with Fill Coat Notes: #7 Initial top of Cement footage measurement was taken from the 4" outlet down to the TOC The 4" conductor outlets are any where from 1 to 3' down from the top of the conductor I DEC Q 6 2019 Permit to Drill 2190700 DATA SUBMITTAL COMPLIANCE REPORT 10/3/2019 Well Name/No. MILNE PT UNIT M-18 C?3-I- r Operator Hilcorp Alaska LLC nN72z0 Completion Date 6/12/2019 Completion Status 1 -OIL Current Status 1 -011 - MID 16731 TVD 3800 REQUIRED INFORMATION Mud Log No ✓ Samples No V DATA INFORMATION C List of Logs Obtained: ROP/ABG/DGR/EWR/ADR 2"/5" MD...ABG/DGR/EWR/ADR 2"/5" TVD PB1, PB2 Well Log Information: 31006 Digital Data Log/ Electr C Data Digital Dataset Log Log Run Interval Type Med/Frmt Number Name _ Scale Media No Start Stop ED C 31006 Digital Data C ED C 31006 Digital Data ED ED C 31006 Digital Data 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data ED C 31006 Digital Data Log 31006 Log Header Scans AOGCC 105 16732 8140 16694 0 0 Page i of API No. 50-029-23632-00-00 UIC No Directional Survey Yes t/ (from Master Well Data/Logs) OHI CH Received Comments 7/19/2019 Electronic File: MPU M-18 LWD Final MD.cgm 7/19/2019 Electronic File: MPU M-18 LWD Final TVD.cgm 7/19/2019 Electronic File: MPU M-18—Definitive Survey Report.pdf 7/19/2019 Electronic File: MPU M-18_DSR.txt 7/19/2019 Electronic File: MPU M-18_GIS.txt 7/19/2019 Electronic File: MPU M-18_Plan.pdf 7/19/2019 Electronic File: MPU M-18_VSec.pdf 7/19/2019 Electronic File: MPU M-18 LWD Final MD.emf 7/19/2019 Electronic File: MPU M-18 LWD Final TVD.emf 7/19/2019 Electronic File: MPU M-18 LWD Final MD.pdf 7/19/2019 Electronic File: MPU M-18 LWD Final TVD.pdf 7/19/2019 Electronic File: MPU M-18 LWD Final MD.tif 7/19/2019 Electronic File: MPU M-18 LWD Final TVD.tif 9/30/2019 Electronic Data Set, Filename: MPU M-18 DGR ABG EWR ADR.Ias 9/30/2019 Electronic Data Set, Filename: MPU M-18 ADR Quadrants All Curves.las 9/30/2019 Electronic File: MPU M-18 Geosteering.dlis 9/30/2019 Electronic File: MPU M-18 Geosleering.ver 2190700 MILNE PT UNIT M-18 LOG HEADERS Thursday, October 3, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/3/2019 Permit to Drill 2190700 Well Name/No. MILNE PT UNIT M-18 Operator Hilcorp Alaska LLC API No. 50-029-23632-00-00 MO 16731 TVD 3800 Completion Date 6/12/2019 Completion Status 1-0I1- Current Status 1-0I1- UIC No Log 31007 Log Header Scans 0 0 2190700 MILNE PT UNIT M-18 PB1 LOG HEADERS ED C 31007 Digital Data 105 10362 7/19/2019 Electronic Data Set, Filename: MPU M-18 P81 DGR ABG EWR ADR.las ED C 31007 Digital Data 8140 10324 7/19/2019 Electronic Data Set, Filename: MPU M-18 1381 ADR Quadrants All Curves.las ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PBI LWD Final MD.cgm ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 P81 LWD Final TVD.cgm ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18PB1_Definitive Survey Report.pdf ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18PB1 DSR.txt ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18PBI GIS.txt ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18PB1_Plan.pdf ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18PB1_VSec.pdf ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PB1 LWD Final MD.emf ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 P81 LWD Final TVD.emf ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PB1 Geosteering.dlis ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PB1 Geosteedng.ver ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PB1 LWD Final MD.pdf ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PB1 LWD Final TVD.pdf ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PB1 LWD Final MD.tif ED C 31007 Digital Data 7/19/2019 Electronic File: MPU M-18 PB1 LWD Final TVD.tif ED C 31008 Digital Data 105 11768 7/19/2019 Electronic Data Set, Filename: MPU M-18 PB2 DGR ABG EWR ADR.las ED C 31008 Digital Data 8140 11730 7/19/2019 Electronic Data Set, Filename: MPU M-18 PB2 ADR Quadrants All Curves.las ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 P82 LWD Final MD.cgm AOGCC Page 2 of 4 Thursday, October 3, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/3/2019 Permit to Drill 2190700 Well Name/No. MILNE PT UNIT M-18 Operator Hilcorp Alaska LLC API No. 50-029-23632.00-00 MD 16731 TVD 3800 Completion Date 6/12/2019 Completion Status 1 -OIL Current Status 1-0I1- UIC No ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 LWD Final TVD.cgm ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18P62_Defnitive Survey Report.pdf ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18PB2 DSR.txt ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18P132GIS.txt ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18PB2_Plan.pdf ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18PB2_VSec.pdf ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 LWD Final MD.emf ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 P132 LWD Final TVD.emf ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 Geosteering.dlis ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 Geosteering.ver ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 LWD Final MD.pdf ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 LWD Final TVD.pdf ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 LWD Final MD.tif ED C 31008 Digital Data 7/19/2019 Electronic File: MPU M-18 PB2 LWD Final TVD.tif Log 31008 Log Header Scans 0 0 2190700 MILNE PT UNIT M-18 PB2 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED AOGCC Page 3 0t'4 Thursday, October 3. 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/3/2019 Permit to Drill 2190700 Well Name/No. MILNE PT UNIT M-18 Operator Hilcorp Alaska LLC MD 16731 TVD 3800 Completion Report 0 Production Test Information y M NA Geologic Markers/Tops YO COMPLIANCE HISTORY Completion Date: 6/12/2019 Release Date: 5/7/2019 Description Comments: Compliance API No. 50-029-23632-00-00 Completion Date 6/12/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No Directional / Inclination Data 0 Mud Logs, Image Files, Digital Data Y � Core Chips Y 1(5 Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files D Core Photographs Y Daily Operations Summary Cuttings Samples Y16 Laboratory Analyses Y➢I Date Comments Date: AOGCC Page 4 of 4 Thursday, October 3, 2019 213070 ueb,a Oudean Hilcorp Alaska, LSC 3 1 0 0W GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Ha.mq� %I4,4a.J.0 Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 09/26/2019 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 RECEIVE® SEP 3 0 2019 AOGCC CD 1: HALLIBURTON FINAL DATA ROP / DGR / Geopilot ABG / EWR-Phase 4 / ADR / Wellbore Profile CGM Definitive Survey EMF LAS PDF TIFF 8/5/20191.07 PM Filefolder 8/5120191:07PM Filefolder 8/5/20191:07 PM Filefolder 8/5/20191:07 PM Filefolder 8./5/20191:07PM Filefolder 8/5/20191:07 PM Filefolder 0-w-� LAS - Li -s 2, Q-) WC -t - Please acknowledge receipt by signing and returning one copy of this transmittalor AX to 907 777.8337 1 , A 1 r %A1 INA 11 A SAM DATE 07/18/2019 2 190 70 benra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 3 1 0 0 6 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU M-18 (PTD 219-070 MPU M-18 PB1 MPU M-18 PB2 CD 1: Log Viewers MPU M-18 MPU M-18 PB1 MPU M-18 P132 7/18/201912:19 PM 7/ 1 8/201 9 1 2:20 PM 7/18/201912:21 PM 7/181201912:22 PM RECEIVED JUL 19 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 J Hik,vp Alu.ko. 1.F.0 DATE 07/18/2019 i Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA CD 1: Log Viewers MPU M-18 MPU M-18 PBI MPU M-18 P82 7/1201912:19 PM 7/1V,201912:20 PM -/13/201912:21 PM 1/18/2019 12:22 Plot 219070 RECEIVED JUL 19 2019 AOGCC 3 100 7 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 MPU M-18 (PTD 219-070 MPU M-18 PB1 MPU M-18 PB2 CD 1: Log Viewers MPU M-18 MPU M-18 PBI MPU M-18 P82 7/1201912:19 PM 7/1V,201912:20 PM -/13/201912:21 PM 1/18/2019 12:22 Plot 219070 RECEIVED JUL 19 2019 AOGCC 3 100 7 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 DATE 07/18/2019 719070 Debra Oudean Hilcorp Alaska, LLC 3 1 0 0 8 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL CD 1: Log Viewers 7/18..201912:19 PM MPU M-18 7/181201912:20 PM MPU M-18 PBl 7x'1°/201912:21 PM MPU M-18 (PTD 219-070 MPU M-18 PB1 MPU M-18 PB2 CD 1: Log Viewers 7/18..201912:19 PM MPU M-18 7/181201912:20 PM MPU M-18 PBl 7x'1°/201912:21 PM MPU M-18 PB2 7/18/201912:22 PM RECEIVED JUL 19 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECOVER JUL 0 9 2019 WELL COMPLETION OR RECOMPLETION REPORT AND 1a. Well Status: Oil Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended F] 1b. Well Class: 20AAC 25.105 2WAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: _ 1 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Abend.: 6/12/2019 219-070 3. Address: 7. Date Spudded: 15, API Number: r 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 May 23, 2019 50-029-23632-00-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: I Surface: 4915' FSL, 561' FEL, Sec 14, T13N, R9E, UM, AK June 5, 2019 MPU M-18 Top of Productive Interval: 1138' FNL, 1688' FWL, Sec 24, T13N, R9E, UM, AK 9. Ref Elevations: KB: 59.1' ' GL: 24.7' SBF: 24.7' ' 17. Field / Pool(s): Milne Point Field Schrader Bluff Oil Pool Total Depth: 790' FNL, 1881' FEL, Sec 30, T13N, R10E, UM, AK 10. Plug Back Depth MD/TVD: 16,726' MD/ 3,800' TVD 18. Property Designation: ADL025514, ADL025515, ADL025517 - 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total DeptttMD/TVD: 19. DNR Approval Number: Surface: x- 533603 y- 6027765 Zone- 4 16,731' MD / 3,800' TVD LONS 16-004 TPI: x- 535885 y- 6021723 ' Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD11VD: Total Depth: x- 542859 y- 6016828 Zone- 4 N/A 2,261' MD / 1,836' TVD 5. Directional or Inclination Survey: Yes L� (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MDffVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, 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 ROP/ABG/DGR/EWR/ADR 2"/5" MD ABG/DGR/EWR/ADR 2"/5" TVD PB1, PB2 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT SETTING DEPTH MD SETTING DEPTH TVD GRADE AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM HOLE SIZE 20" 216# X-52 Surface 114' Surface 114' 42" ±270 ft3 9-5/8" 40# L-80 Surface 8,155' Surface 3,726' 12-1/4" Stg 1 L - 885 sx / T - 400 sx Stg 2 L - 437 sx / T - 270 sx 245 bbls 7" 26# L-80 Surface 8,024' Surface 3,722' Tieback Tieback Assy.* 6-5/8" 20# L-80 8,014' 16,731' 3,721' 3,800' 8-1/2" Cementless Slotted Liner 24. Open to production or injection? Yes Q No ❑ 25. TUBING RECORD If Yes, list each interval open (MDr VD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Pend): 3-1/2" 8,046' 1 6,771' MD / 3,425' TVD 6-5/8" slotted liner run on 6/9/19 "please see attached schematic for slotted/solid liner detail"' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, COMPLETION Was hydraulic fracturing used during completion? Yes No Q D TE Per 20 AAC 25.283 (i)(2) attach electronic and printed information Z J� DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED V 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 6/28/2019 Jet Pump Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 7/5/2019 24 Test Period 981.5 410.4 1479 N/A 417 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 326 3500 24 -Hour Rate -.0. 981.5 410.4 1479 16 Form 10-407 Revised 5/20171/,f,•li � � O ,/p CONTINUED ON PAGE 2 RBDMS JUL 1 y YO,Jubmit ORIGINAL orylq. zA{LL�n(! I M83/3011% 9 (lJ� 28. CORE DATA Conventional Corals): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/ro), 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, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8,160' SB OA 3,726' information, including reports, per 20 AAC 25.071. SV5 1,371' 1,309' , SV1 2,363' 1,872' Ugnu LA3 5,961' 3,119' SB NA 7,012' 3,499' SB OA 7,988' 3,717' Formation at total depth: SB OA ' 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Survey, Csg and Cmt Report, OH Sidetrack Summary 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. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: WIling Manag Contact Email: Cdinger(dihllCOr .com Authorized NfN •� /� Contact Phone: 777-8389 Signature: Date: Tf/ INSTRUCTIONS General: 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. Item 1 a: 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. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: 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. Form 10407 Revised 5/2017 Submit ORIGINAL Only Hilcary Alaska, LLC Orig. KB Elev.: 59.1'/ GL Elev.: 24.7 2a' Cameron 31/8" 5M Wellhead FMC 11" SM TC -1A w/11" x 31/2" TC -II Top and Bottom Tubing 12-1/4" 2nd stage ssa Es 8-1/2" Cementless Slotted Liner in 8-1/2" hole Conductor (insulated) 215.5/A-53/Weld Cerrerrta @ •. Surface 114' N/A 9-5/8" 2,489 40/L-80/TXP 8.679" Surface 8,155' 0.0758 7" Tieback 26/L-80/TXP IN A Surface 8,024' 2 6-5/8" Slotted Liner 3 1/2" 5.924" 8,014' 16,731' V 2.885" 8 6,797' 3 4 9 8,045' 4 2.867" Lower Completion 10 vl BOTSLZXP Liner Top Packer w/BD Slips 7"x9-5/8" 6.170" 11 5 7" Tieback Assy. (8.25" OD No -Go) 7" 12 8,036' 7" Hydril 563 L-80 x 6-5/8" Hydril 563 L-80 XO d 14 16,726' WIV(Ball On Seat) - N i 8 7 i; 70 A 7i2 - 6-5/8' 8-1/2" Shoe @VII Hole .16,731 13 TD =16,731' (MD) / TD = 3,8W(TVD) PBTD=16,726 (MD) / TD = 3,800•(TVD) SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU Moose Pad M-18 Last Completed: 6/12/19 PTD: 219-070 Tree Cameron 31/8" 5M Wellhead FMC 11" SM TC -1A w/11" x 31/2" TC -II Top and Bottom Tubing 12-1/4" 2nd stage Hanger with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. OPEN HOLE / CEMENT DETAIL 42" 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4" 1st stage L-885 sx/T-400 sx 12-1/4" 2nd stage L-437 sx/T-270 sx 8-1/2" Cementless Slotted Liner in 8-1/2" hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20"x34" Conductor (insulated) 215.5/A-53/Weld N/A Surface 114' N/A 9-5/8" Surface 40/L-80/TXP 8.679" Surface 8,155' 0.0758 7" Tieback 26/L-80/TXP 6.151" Surface 8,024' 0.0383 6-5/8" Slotted Liner 20/L-80/Hydril 563 5.924" 8,014' 16,731' 0.0355 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE 1 2.867" 1 Surf 1 8,046' 0.0087 WELL INCLINATION DETAIL KOP @ 32U Max Hole Angle = 67 @ Jet Pump Max Hole Angle = 68 @ XN profile Max Hole Angle = 86 @ Tubing tail Max Hole Angle = 95.6 JEWELRY DETAIL No. Top MD Item Drift ID 8,160' 3,726' Upper Completion 10,493' 1 29' Tubing Hanger (3-1/2" TC -II Top 8, Btm) w/ Blast Rings on hanger pup 2.867" 2 3,102' 3.5" GLM w/ 1.5" SOGLV set (2,000 psi shear) 2.867 3 6,708' 3.5" Discharge Pressure Gauge Mandrel (Discharge Gauge) 2.875" 4 6,719' 3.5" XD Sliding Sleeve 2.813" Packing Bore 2.813" 5 6,728' 3.5" Gauge Mandrel w/ Y" Wire (Intake Gauge) 2.875" 6 6,749' 3.5" X Nipple (2.813" Packing Bore) 2.813" 7 6,771' 7" x 3.5" PHIL Retrievable Packer (50k Shear Release) 2.885" 8 6,797' 3.5" XN Nipple (2.813" Packing Bore; 2.75" No -Go) Min ID = 2.750" RHC -P set 2.750" 9 8,045' 3.5" WLEG 2.867" Lower Completion 10 8,014' BOTSLZXP Liner Top Packer w/BD Slips 7"x9-5/8" 6.170" 11 8,024' 7" Tieback Assy. (8.25" OD No -Go) 6.151" 12 8,036' 7" Hydril 563 L-80 x 6-5/8" Hydril 563 L-80 XO 5.924" 14 16,726' WIV(Ball On Seat) - 4-1/2" SOLID LINER DETAIL 1[s Top Top Btm Btm (MD) (TVD) (MD) (TVD) 3 8,040' 3,723' 8,160' 3,726' 3 10,493' 3,772' 10,611' 3,770' 5 10,971' 3,755' 11,172' 3,743' 5 13,912' 3,747' 14,113' 3,761' 4-1/2" Slotted LINER DETAIL Its (Top) Top (TVD) Btm (MD) Btm (TVD) 58 8,160' 3,726' 10,493' 3,772' 9 10,611' 3,770' 10,971' 3,755' 68 11,172' 3,743' 13,912' 3,747' 64 14,113' 3,761' 16,690' 3,801' GENERAL WELL INFO API: 50-029-23632-00-00 Drilled and Completed by Doyon 14-6-12-19 Revised By: OD 7/8/2019 U Well Name: MP M-18 Field: Milne Point County/State: , Alaska (LAT/LONG): ovation (RKB): API #: Spud Date: Job Name: 1911313D MPU M-18 Drilling Contractor Doyon 14 AFE #: AFE $ Hilcorp Energy Company Composite Report Activity Datet'ra'ms' OpsSummary 5/22/2019 See M-16 for details.;Skid Rig floor into moving position & move off Well M-16.;Move, spot & shim Rig, level, over Well M-18.,Skid Rig floor into Drilling position, Spot Rockwasher into place - Berm Cuttings Tank.;Crient surface annular and knife valve for diverter line placement. Install 16" Diverter line. Sim ops: Prep mud pits for mud and rig up stream, air and water to the rig floor. Move rig mats from rig move.;C/O Saver Sub, Work on Rig acceptance checklist, finish torque bolts on surface annular, knife valve Tee and diverter line. Load 5" drill pipe into pipe shed and begin processing. Continue M/U Bell Nipple, Surface riser and tum buckles.;Finalize acceptance checklist, Rig accepted at 01:00. Rig off Cat power at 17:30 to bring on hi -line power. Breaker tripping, change out 2000amp breaker. "' On high line power at 21:40 "'.;Finish processing 264 joints of 5" drill pipe and load 17 joints of 5" HWDP in shed. Prep mud pits and shakers for surface hole.;Pick up and rack back 15 stands 5" drill pipe, 5/23/2019 Continue build stands of 5" drill pipe in mouse hole and rack in Derrick. 62 stands racked back;Finish picking up remaining 78 joints of 5" drill pipe and rack in Derrick. Total of 88 stands in Derrick to drill surface hole.;P/U 17 joints of 5" HWDP & Jars and rack in the Derdck.;Perform diverter function test on 5" drill pipe. " Test witness waived by AOGCC insp Austin McLeod @ 08:53, 5/22/2019"' Knife valve opened in 16 seconds & annular closed in 27 seconds. Accumulators: 3000 PSI system, 1850 PSI after closure, 36 sec. 200 PSI recharge, 153 sec. full recharge, 2012 PSI.;240' of 16" diverter line installed, 160' from closest ignition source, 203' from rig sub structure.;Sewice TopDrive, Service conveyor, Clean rig floor, Function and flush centrifuges, Function gas buster and flush. Strap and Tally drilling BHA components.;Pre-spud meeting with Doyon, MI and Sperry. M/U new 12-1/4" Kymera bit, 8" SperryDrill motor set at 1.5% XO sub and stand of 5" HWDP. RIH at tag bottom on depth at 114'. Flood lines and pressure test to 3500 PSI - good test.;Drill 12-1/4" surface hole from 114' to 220', 106 drilled, 1497hour AROP. 424 GPM = 800 PSI, 40 RPM = 1.SK TQ, 6K WOB. PU 50K / SO 50K / ROT 50K. 8.8 ppg MW, 300+ vis.;Back ream out at 40 rpm F/ 220'T/ 114'. Circ two btm up clean. Blow down TD & Clean and clear rig floor.;M/U Remaining Directional BHA #1 with DM Collar, DGR, EWR, PWD HCIM & TM Collar, Carry Scribe and upload MWD. P/U 3 NMFC & RIH to 193'.;Shallow hole test tools and wash down F/ 191' T/ 220'. Obtain MWD Survey.;Drill 12-1/4" surface hole from 220' to 256', 448 GPM = 930 PSI, 40 RPM = 1.5K TQ, 7K WOB. PU 55K / SO 63K / ROT 64K. 8.7 ppg MW, 300+ vis.;Hauled 730 bbls H2O from 6 Mile lake for total = 730bbls Hauled 0 bbls heated H2O from G&I for total = 0 bbls Hauled 0 bbls cutting/liquids to MPU G&I for total= 0 bbls 5/24/2019 Drill 12-1/4" surface hole F/ 256' T/ 807'448 GPM = 1150PSI, 40 RPM = 2-4K TQ, 7K WOB. PU 80K / SO 76K / ROT 64K. 8.7 ppg MW, 180+ vis. 9.7 ECD = W 9.O.;Drill 12-1/4" surface hole F/ 807' T/ 1692'. 448 GPM = 1500PSI, 70 RPM = 6-8K TO. 7K WOB. PU 80K / SO 76K / ROT 64K. 8.7 ppg MW, 199+ vis. 9.7 ECD =MW 9.O.;Drilling 12.25" hole F/ 1692'T/ 2458' MD /1835' TVD, 766 @ 127 FPH avg. 488 GPM, 1450 PSI, 80 PRM, 5K TO, 7K WOB. 9.4 ppg MW, 300 vis. 10.7 ppg ECD. Max gas 17 units. 101k PU / 80k SO / 90k ROT.;End of build at 2207', maintain 69' tangent. Base of permafrost at 2261' MD / 1836' TVD.;Drilling 12.25" hole F/ 2458' T/ 3407' MD / 2238' TVD, 949 @ 158 FPH avg. 550 GPM, 2000 PSI, 90 PRM, 9.2K TQ, 5-15K WOB. 92 ppg MW, 142 vis. 10.4 ppg ECD. Max gas 15 units. 115k PU / 76k SO / 95k ROT.;Pumped high vis sweep with nut plug at 2700', 20% increase and back on calculated strokes. ECD climbed to 12.2 ppg while drilling stand to 3027', reamed stand 2x, dropped ECD to 10.8 ppg. Hard formation or bit balling after connection from 3030' U 3040' helped drop ECD's further t/ 10.2 ppg.;Last survey at 3258.32' MD / 2184.96' TVD, 68.99' Inc, 164.33' azm, 3.61' from plan, 1.98' high and 3.02' right.;Hauled 1320 bbls H2O from 6 Mile lake for total = 2050 bbls Hauled 0 bbls heated H2O from G&I for total = 0 bbls Hauled 1502 bbls cuttinalliauids to MPU G&I for total= 1502 bbls 5125/2019 Drilling 12.25" hole F13407' T! 4340' MD / 2564' TVD, 933'@ 155 FPH avg. 600 GPM, 2180 PSI, 80 PRM, 8K TO, 8-10K WOB. 9.1 ppg MW, 125 vis. 10.4 ppg ECD. Max gas 21 units. 125k PU / 76k SO / 99k ROT. Top of Ugnu (UG4) = 3419 MD, 2244' TVD.;Drilling 12.25" hole F/ 4340' T/ 5027' MD / 2809' TVD, 687'@ 125 FPH avg. 600 GPM, 2330 PSI, 80 PRM, 7-11 K TO. 13-15K WOB. 9.2 ppg MW, 120 vis. 10.3 ppg ECD. Max gas 20 units. 150k PU / 80k SO / 110k ROT.;Pumped high vis sweep with nut plug at 4952', 0% increase and back on calculated strokes.;Circulate sweep out at Kelly down with 8.6 BPM - 1060 psi, 50 RPM - 11 k Tq. Change out Swab on #1 Mud Pump.;Drilling 12.25" hole F15027' T/ 5742' MD / 3040' TVD. 715'@ 130 FPH avg. 600 GPM, 2260 PSI, 80 PRM, 13-15K TQ, 13-15K WOB. 9.1 ppg MW, 75 vis. 10.0 ppg ECD. Max gas 102 units. 162k PU / 73k SO / 113k ROT.;Drilling 12.25" hole F/ 5742' T/ 654V MD / 3342' TVD, 806'@ 134 FPH avg. 600 GPM, 2320 PSI, 80 PRM, 15K TQ, 5-8K WOB. 9.3 ppg MW, 72 vis. 10.3 ppg ECD. Max gas 20 units. 126k PU / 80k SO / 119k ROT.;Last survey at 6494.73' MD / 3320.25' TVD, 69.37" inc, 162.70° azm, 1.96 from plan, 1.19' high and 1.57' right.;Hauled 760 bbls H2O from 6 Mile lake for total = 2810 bbls Hauled 790 bbls H2O from B Pad Creek for total = 790 bbls Hauled 0 bbls heated H2O from G&I for total = 0 bbls Hauled 2075 bbls cuttin /li uids to MPU G&I for total= 3577 bbls 5/26/2019 Drilling 12.25" hole F/ 6548'T/6958 MD 410' @ 68 FPH avg. 600 GPM, 2420 PSI, 80 PRM, 15K TQ, 20K WOB. 9.3 ppg MW, 72 vis. 9.8 ppg ECD. Max gas 192 units. 190k PU / 77 k SO / 120k ROT. Slow drilling adding lubes for sliding at 1%. Helping, Shakers Blinded off in Ugnu MB. Added screen clean .;Drilling 12.25" hole F/ 6958' T/ 7501' MD 543' @ 90 FPH avg. 600 GPM, 2320 PSI, 80 PRM, 20K TO, 19-21 K WOB. 9.3 ppg MW, 84vis. 10.3 ppg ECD. Max gas 125 units. 190k PU / 75k SO / 120k ROT. Slow drilling adding lubes for sliding at 1 %. Helping.;Drilling 12.25" hole F/ 7501' T/ 7975' MD 474' @ 79 FPH avg. 600 GPM, 2600 PSI, 80 PRM, 22K TO, 20-22K WOB. 9.3 ppg MW, 72 vis. 10.3 ppg ECD. Max gas 122 units. 195k PU /75k SO / 120k ROT. Maintaining lubes at 1%.;Drill 12.25" hole F/ 7975'T/ 8162' (3726' TVD) 187'@ 125 FPH average. TD Called at 8162'. 600 GPM, 2690PSI, 80 RPM. 23K TQ, 2-20K WOB. 9.4 ppg MW, 614 vis, 10.1 ppg ECD. Max gas 172 units. 194K PU / 73K SO 1121 K ROT.;Last survey at 8107.51' MD / 3726.52' TVD, 90.68° inc, 124.69° azm, 26.71' from plan, 26.61' low and 2.24' left. Top of Schrader Bluff OA -1 at 7988' MD / 3718' TVD.;Pull two stands while circ sweep around at 600 GPM, 80 RPM, Sweep came back on time with Minimal (10%) increase in cuttings. Clean hole. RIH back to him, perform flow check - static and start back reaming out.;Back ream out from 8162' to 7148' at 550 GPM, 2200 PSI, 80 RPM, 21.2K TQ, 10.02 ppg ECD. 5-10 min per stand slowing down if pressure, TO, or drag increases.;7543' pulled 25K over and torqued up to 25K, 600 psi pressure increase, pumps off and RIH to 7553' then back ream clean. 7148' pulled 20k over and string & motor stalled. Shut pumps and rotary off.;TopDrive kicked off while working torque out of string, backspin @ 177 RPM. Re- set TopDrive and torque back into string, 25k, stalled, released torque. Establish flow 375 GPM. PIU, Jars actuated at 301k over and string came free. Pressure back to normal.;Hauled 0 bbls H2O from 6 Mile lake for total = 2810 bbls Hauled 1385 bbls H2O from B Pad Creek for total = 2175 bbis Hauled 0 bbis heated H2O from G&I for total = 0 bible Hauled 1271 bbis cutting/liquids to MPU G&I for total= 4848 bbls 5/27/2019 Back ream up full stand 717100'. Orientate to slide. RIH past tight spot no issues. Stage up pumps and back ream up & saw tights spot with motor stalling again. Hammer down free. Back ream up slow & let clean up. Pulled clean after tight spots around 7148'.;Back ream out from 7100' T/ 6800' at 550 GPM, 2200 PSI, 80 RPM, 16-20 TQ, 10.02 ppg ECD. 10 min per stand slowing down if pressure, TQ, or drag increases. Backream in to tangent and pulled clean other than slide areas. Slight Pressure increases.;Back ream out at 550 GPM, 80 RPM 5-10 Min per stand F/ 6800' T/ 2175'. Getting cuttings increase at shakers. Pulling slower to let clean up. No Iosses.;Back ream out at 550 GPM, 80 RPM 5-10 Min per stand F/ 2175' T/ 844'. Pulled slow and reduce pump rate to accommodate shakers blinding from 1590' U 1566'.;Attempt to pump out last stand with no rotary, 600 GPM, 1480 psi. Pulled tight at 770' with 15k over. No pressure increase. Pumps off, run stand down and backream out @ 550 GPM, 40 RPM.Torque 7-9k w/ 15k spikes. Ratty the whole stand. Pumps off and run std back in, pump out with no rotary @ 450 GPM.;Continue backream out HW DP 1 stand U 655'@ 500 GPM; 1040 psi, 40 RPM; 7-9k Tq. Torque cleaned up last 10' of stand. Shakers have some sand coming across, cleaned up significantly from previous stand.;Pull out of hole on elevators from 655' to 191' racking HWDP & Jars in Derrick. No issues. Hole took proper fill throughout backream and trip out.;UD BHA & Drain motor. Break out bit. Bit grade- 3 -6 - LT -S -F -3 -BT -TD. Clean and clear rig floor.;R/U to run 9-518" Casing with Doyon casing. M/U Volant tool with Cmt swivel to TD & install bail extensions. Install XO on FOSV.;P/U 9-5/8" shoe track to 162'. Baker Loc shoe track and torque to 20,960 fil Two 9-5/8"x12-1/4" Expand-o-lizers on shoe joint and 1 each on spacer and float collar joint. Check floats. Good. Pump through with Volant.; Run 9-5/8" 40# L-80 TXP BTC -SR casing as per tally, filling on the fly with Volant and breaking circ every 10 joints F/ 162' T/ 1172'. Torque to 20,960 ft/lbs w/ Volant. One centralizer per joint to #25 and every other to #137. 20-40'/min running speed. 19.1 bbls lost. 5/2 812 01 9 Run 9-5/8"" 40# L-80 TXPBTC-SR casing as per tally, filling on the fly with Volant and breaking circ every 10 joints F/ 1172' T/ 3158'. Torque to 20,960 ftllbs W/ Volant.. One centralizer every other joint.;Circ & condition staging up pumps to 6 bpm @ 300 psi. UP/DN 140/96K. Cleaned up at btm up. MW 9.4 Vis 112.;Run 9-5/8" 40# L-80 TXP BTC -SR casing as per tally, filling on the fly with Volant and breaking circ every 10 joints F/ 3158'T/ 5280'. Torque to 20,960 fUlbs w/ Volant. One centralizer every other joint to #138, One everyjoint to 148. Place Halliburton ESIPC between joints #143 & 144.;Baker lock above and below ESICP. Continue to RIH with 9 5/8 Casing F/ 5663 T/ 6709. Filling on the fly with Volant and breaking circ every 10 joints. Torque to 20,960 ft/lbs w/ Volant. Centralizer on every other joint to #104.;Circ & condition staging up pumps to 6 bpm @ 480 psi. UP/DN 270195K. 4 bbis lost while circulating. MW 9.4 Vis 54.;Continue to RIH with 9 5/8 Casing F/ 6709'T/ 8106. Wash down F/ 8105' to 8159'w/ 2 BPM, 320 psi. Filling on the fly with Volant and breaking circ every 10 joints. Torque to 20,960 ft/lbs w/ Volant. Centralizer on every other joint to #202 Total of 205 joints, 121 centralizers & 10 stop rings ran.;136.5 bbis mud lost while running casing.;Stage up pumps F/ 2 BPM, 320 psi T/ 6 BPM, 440 psi while reciprocating pipe F/ 8159'T/ 8129'. Rotate 5 RPM w/ 251(torque. Circulated 1.2 bottom up. PJSM w/ Doyon, Halliburton, M-1 and Peak.;Shut down, blow down top drive and rig up cement lines. Pump 5 bbis water, pressure test lines to 1000 psi low & 4000 psi high.;Mix & pump 60 bbis 10.0 ppg Clean Spacer w/ 4# red dye and 5# Pol-E-Flake in 1st 10 bbls at 4 BPM, 250 psi. Drop by-pass plug. Mix & pump 371.2 bbis 12.0 Lead Cement (885 sks, 6.146 laid at 6.0 BPM, 380 psi. Mix & um 82.4 bbis 15.8 Tail Cement 400 sks, 1.157 yield) at 3.0 BPM, 250 psi.;Drop shut off lu . Pum 2 bbis of water. Displace with 9.4 ppg spud mud with rig pumps at 6.0 BPM, 170 psi ICP, 730 psi FCP. Pump 100 bbis water with Halliburton at 6 BPM, 900 psi ICP, 1190 psi FCP. Continue to displace with rig pumps at 4 BPM, 770 psi. Increase to 6 BPM, 930 psi ICP, 960 psi FCP.;560 psi lift observed before pumping the 100 bbis of water. Slow for last 10 bbis to 3 BPM, 760 psi. Plug bumped at 4889 strokes, 46 strokes over calculated. CIP at 05:50. Rotated 5-10 RPM w/ 25K torque and reciprocated 20' during entire cement job.;Pressure up to 1310 psi, hold for 5 min. - good. Bleed off and check floats - good.;Hauled 0 bbis H2O from 6 Mile lake for total = 2810 bbis Hauled 375 bbis H2O from B Pad creek for total= 3100 bbis Hauled 660 bbis heated H2O from G&1 for total = 660 bbis Hauled 426 bbis cuttingiliquids to MPU G&I for total= 6589 bbis 140.5 bbis daily losses, 140.5 bbis cumulative losses. 5/29/2019 Pressure up at 3 bpm to open tool. Saw packer inflate at 1800 psi & tool open at 2030 psi. Established returns with high circ pressure. Pump 5-6 bpm loosing 25% returns and pressure 2700-2900 psi. Lost 75 bbl on first btm up but we did see poly flake.;Continue to circ 3.5 btms up. Pressure dropped slowly from 2800 down to normal pressures around 750 at after 1.8 btms ups. Saw better flow after getting water out of the tool and mud turned the corner.;Lost 75 bbl while pumping the first btm up and Saw mud push & 10 bbl est cmt at btm up plus 75 bbl lost. Saw contaminated mud for another btm up. Dump all to rock washer. Not clobbered up just thick mud smooth. Cleaned up at 2.5 btm up total pumped. Take mud back to the pits.;Shut down and flush out stack with black water. Function annular. Line up and pump high vis sweep around and sweep brought back nothing. Smooth mud the whole time. Circ total of 3.75 btm up total at 4-6 bpm while prepping for second stage. Conduct PTSM & cmt pre job with crew coming on.;Batch up spacer & line up to HES. Pump 60 bbl of lean 109 spacer with red dye and .5 ppb Poly flake in the firs 10 bbis. , Pump 383 bbis of 10.7# lead Perm L Cmt. ( 437 SX) 4-6 BPM. Got good mud push ^back `�... on time. Got good cmt back on calculated strokes also. 10.5 MW at start of cmt.;Pump 56.2 bbl of 15.8 Tail cmt. (270 SX) Drop closing plug and chase with 20 bbl H2O From HES. Line up to rig for displacement Pump 1600 strokes at 5 BPM. Bump plug two strokes early at 3 bpm 1671 stks & Pressure up S to 1500 psi over FCP at 480 psi. Hold 2000 psi. Bleed down. No flow.;No losses on second stage. No clobbered up issues on second stage. CIP at 15:47 with 245 bbl good lead cmt back at surface.;Flush all surface equipment with black water. Drain stack, N/D diverter line and lift 20" diverter equipment. Install casing slips as per wellhead rep. with 100K on slips. Rough cut casing.; N/D surface diverter stack. Clean and clear rig floor of casing tools and equipment.;Perform final out of 9-5/8" casing (22.51' total cut). Install FMC slip lock head, tubing spool and casing spool. Test slip lock head to 500 PSI for 5 min. and 2475 PSI for 10 min. - good tests.;N/U BOP stack. Install trip nipple, turn buckles and MPD 4" line to MPD head. Torque casing and tubing spool bolts. Sim -ops: clean mud pits, prep rig floor for testing.;lnstall test plug & 5" test joint. R/U test equipment and flood lines. Test plug seal leaking. Pull test plug, install new seal then re -install test plug. Test plug seal leaking. Call wellhead rep, pull test plug - found tear in seal. "' Notified AOGCC of initial BOP test on 5- 28-2019 at 15:47 "';Hauled 0 bbis H2O from 6 Mile lake for total = 2810 bbis Hauled 230 bbis H2O from B Pad creek for total= 3330 bbis Hauled 290 bbis heated H2O from G&I for total = 950 bbls Hauled 2249 bbls cutting/liquids to MPU G&I for total= 8838 bbls 116 bbis daily losses, 256.5 bbls cumulative losses. 5/30/2019 Replace gasket seal on test plug, re -install - holding fluid. Fill stack & pump through gas buster.;Test BOP equipment as per PTD & AOGCC requirements witnessed byAOGCC rep. Jeff Jones Pressure up good shell test, Oteco flange on choke line leaking. Disconnect, clean flange & install new Oteco gasket. All tests performed w/ fresh water against test plug.;All tests performed to 250 PSI low / 3000 PSI high. All tests held for 5 min. each. #1: Annular on 5" test joint, choke valves 1, 12,13.14, 3" kill Demco & upper IBOP. #2: Top 4.5"x7" VBR on 5" test joint, choke valves 9, 11, HCR kill & lower ISOP. #3: Choke valves 5,8,10, manual Will & 5" TIW #1.;#4: Choke valves 4,6,7 & 5" TIW #215: Choke valve 2 & 5" dart valve.#6: Lower 2-718"x5" VBR on 5" test joint.#7: Annular on 3.5" test joint & HCR choke.#8: Lower 2-7/8"x5" VBR on 3.5" test joint. #9: Top 4.9'x7' VBR on 7" test joint & manual choke.;#10: Blind rams, choke valve 3 & 3.5" TIW. #11: Hyd choke A #12: Man choke B Accumulator test: 3000 PSI system pressure, 1725 PSI after closure. 45 sec for 200 PSI recharge, 189 sec for full PSI recharge. 1907 PSI six nitrogen bottle average.;Fail/Pass three tests. Choke line connection during shell lest, changed seal ring - retested good. Choke valve #8 cycled & greased - retested good. Accumulator leak on railroad union, retightened - good.;R/D test equipment and blow down lines. Install 9" I.D. wear bushing. Mobilize BHA components to the rig floor. Inspect top drive saver sub - good.;M/U 8-112" cleanout BHA. Used 8-1/2" Hughes VM -3 bit, 7" mud motor, float sub and 3 NM flex collars to 122'. TIH with 5" HWDP & jars f/ 122't/ 680'. Single in the hole w/ 5" drill pipe from the pipe shed f/ 680' t/ 2452'.;Wash down f/ 2452't/ 247T& tag cement wl 10K. Drill cement If 2477' to 2486 w/ 450 GPM, 900 PSI, 40 RPM, 5K TQ. Drill ES cementer f/ 2486' tt 2496 & continue down to 2502'. Ream 2x times, then pull up to 2485'& down to 2515' with no pumps -good. Blow down top drive. 104K PU /75K SO / 90K ROT.;Continue to PIU 5" drill pipe from the pipe shed f/ 2515't/ 2674'. TIH out of the derrick f/ 2674' U 3813'.;Perform kick while tripping drill. Well secure in 1 min. 45 sec. & all hands responded in 2 min. 13 sec. Perform well kill drill w/ both rig crews. Shut annular & trap 200 PSI for SIDP. Fill out kill sheet & circ through choke & cycle rig personnel on choke control. Sim -ops: work on ST -80 spinner.:Service top drive, blocks and draw works. Sim -ops: work on ST -80 spinner.;Replacing hydraulic motor on ST -80 spinner did not fix ST -80 iron roughneck. Source replacement transmission. Doyon 19 had opposite side. Found sheared pinion in transmission. Disassemble Doyon 19 part to see if pinion was the same. Source spinner hawk from Doyon yard.;Write new procedure for utilizing spinner hawk and rig tongs. PJSM with rig crew. R/U spinner hawk.;Losses today to hole= 0 bbis. Total losses for interval= 256.5 Hauled 0 bbis H2O from 6 Mile lake for total = 2810 bbis Hauled 130 bbis H2O from B Pad creek for total= 3460 bbis Hauled 0 bbis heated H2O from G&1 for total = 950 bbis Hauled 56 bbis cutting/liquids to MPU G&I for total= 8894 bbis 5/31/2019 RIH F/ 3813' T/ 7673'. Tag up hard. Had drag while running in the hole from ESIPC. Break Circulation and wash and ream down F/ 7682'T/ 7997'. RIH using spinner hawks and Rig Tongs.;R/U & Test casing to 2500 psi for 30 min. Good. Bleed down and blow down surface equipment.:Wash & Ream F17997' T/ 8031'. Tag bfl adaptor on depth. UP/ROT 225K11 20K 50 rpm. 16-18k.;Drill Baffle adaptor, Float Collar & shoe on depth. Good cmt. Drill rat hole out T/ 8162'. Drill 20 New hole F/ 8162'T/ 8182'. 50 RPM, 18K TQ. 400 GPM, 1300 PSi.;Ream through shoe & FE several times. No down wt to slide through shoe. Pull in to shoe & Bring pumps to 550 GPM. Work pipe 60' Circulating btm up. Good 9.35 in and out. Two btm up. Got lots of cmt back through second btm up.;Perform Kick drill with crew and the after action review. CRT 256 well secure. Motor man on the brake. Good Drill. Lead crew through choke drill and bringing the pump up to speed and then down again holding Min hole pressure constant. Had three different choke operators. Crews first time.;Perform FIT to 12 PPG EMW. 510 PSL Good test. Held for 10 min. Bled down 75 psi. Good test. Blow down surface equipment. MW 9.35, EMW 12,510 PSI TVD 3724'.;POOH F/ 8150' T/ 689. Observed high drag causing surface vibration while tripping. Slow pulling speed until vibration diminished. Pumped dry job at 7136. UD 16 joints of HWDP. Rack back one stand HWDP w/ jars and NMDC. L/D motor and bit. Bit graded: 1-3-BT-M-E-1-NO-BHA.;Clear rig floor and mobilize new BHA to the rig floor. M/U 8-1/2" production drilling BHA to 83': SK616MJI D bit, NRP sleeve, Geo -Pilot, MWD (ADR/DGR/PW D/DWTM) then initialize tools. M/U 2 float subs then TIH 3 NM flex collars, HWDP & jars to 276. Pulse test MWD 450 GPM, 870 PSI - good.;Single in the hole with 5" drill pipe from the pipe shed 11275' t/ 2660'. Fill pipe every 20 stands.;Hauled 0 bbis H2O from 6 Mile lake for total = 2810 bbls Hauled 90 bbis H2O from B Pad creek for total= 3550 bbis Hauled 0 bbis heated H2O from G&I for total = 950 bbis Hauled 112 bbis cutting/liquids to MPU G&I for total= 9006 bbis 0 bbis daily losses, 256.5 bbis cumulative losses. 6/1/2019 Single in the hole with 5" drill pipe from the pipe shed f/ 275' U 6944', then TIH f/ 6944' V 8084'. Fill pipe every 20 stands.;PJSM. Remove trip nipple and install MPD RCD. Flood lines and flow through MPD chokes.;M/U stand of drill pipe and RIH to 8182'. Displace wellbore from 9.2 ppg spud mud to 8.8 ppg Flo -Pro NT at 6 BPM, 660 PSI, 50 RPM, 19K TO. Reciprocate pipe 60' from 8153' to 8093'.;Slip and cut drilling line and service rig while allowing time to clean pits.;Drill 8-1/2" production hole f/ 8182' U 8605' (3741' TVD), 423' drilled, 84.67hr AROP. 550 GPM, 1820 PSI, 120 RPM, 17K TQ, 5-15K. WOB. 205K PU / 45K SO 1110K ROT. 8.9 MW, 44 vis, 10.47 ppg ECD, 178u max gas. Entered OA -2 @ 8321'& OA -3 @ 8455'.;MPD chokes full open while drilling, closed on connections with no pressure obsewed.;Drill 8-1/2" production hole f/ 8905' U 9410' (3751' TVD), 505' drilled, 84.27hr AROP. 555 GPM, 1910 PSI, 120 RPM. 15K TO, 5-8K WOB. 175K PU 170K SOW / 109K ROT. 9.0 MW, 45 vis, 11.0 ppg ECD, 166u max gas. Pumped hi vis sweep @ 9222', 30% increase back on calculated strokes.;No SOW @ 8645', added 0.5% Lo -Torp lubes & had 70K SOW. Torque down 1:1 15K f/ 20K, PUW down t/ 175K f/ 213K. Surface pipe vibration went away. MPD chokes full open while drilling, closed on connections w/ no pressure observed. Drilled 6 concretions for a total thickness of 56' (4.9% of the lateral).;Last survey @ 9341.19' MD / 3752.06' TVD, 90.01' inc, 126.19° azm, 3.3' from plan, 1.16' high & 3.09' right.;Losses today to hole= 0 bbls. Total losses for interval= 0 Hauled 0 bola H2O from 6 Mile lake for total = 2810 bible Hauled 60 bbls H2O from B Pad creek for total = 3610 bbis Hauled 30 bbis H2O from M -Pad for total = 30 bbis Hauled 0 bbis heated H2O from G&I for total = 950 bbl 6/2/2019 Drill 8-1/2" production hole V 9410't/ 10155' (3745' TVD), 745' drilled, 124.27hr AROP. 535 GPM, 1950 PSI, 120 RPM, 13K TO, 5-10K WOB. 8.9 MW, 43 vis, 10.9 ppg ECD, 289u max gas. 160K PU / 70K SO / 109K ROT. Entered OA -2 @ 10030' and OA -1 @ 10123'.;Drill 8-1/2" production hole f/ 10155' U 10362' (3760' TVD), 207' drilled, 1387hr AROP. 550 GPM, 2060 PSI, 120 RPM, 14K TO, 5-15K WOB. 8.9 MW, 44 VIS, 11.1 ppg ECD, 270u max gas. 155K PU / 70K SO / 105K ROT. Drilled out the top of OA -1 @ 10205' due to dip change.;BROOH V 10362't/ 9990', 550 GPM, 2080 PSI, 120 RPM, 14K TQ.;Trough 20' observed 2.1 ° drop in inclination. Control drill @ 507hr until 90" inc. Sidetrack low side and drill f/ 9990't/ 10362' (3761' TVD), 372' drilled, 74.47hr AROP. 8.9 MW, 44 vis, 10.9 ppg ECD, 171 u max gas. 155K PU / 65K SO / 105K ROT.;Trip back through sidetrack point. BROOH f/ 10362' U 9983', 550 GPM, 2080 PSI, 120 RPM, 14K TQ. TIH on elevators f/ 9983't/ 10362', 180K PU / 70K SO. At bit inclination of 86.79° verified assembly tripped into the new hole.;Drill 8- 1/2" production hole f/ 10362't/ 1069T (3767' TVD), 331' drilled, 94.67hr AROP. 550 GPM, 2200 PSI, 120 RPM, 12K TO, 5-15K WOB. 9.0 MW, 45 vis, 11.3 ppg ECD, 171 u max gas. 150K PU / 65K SO 1102K ROT.;Crossed fault #1 (20' DTN) @ 10364' f/ OA -1 to OA -3, then fault #2 (11' DTN) @ 10461' out of OA - 3 to shale below OA -4. Built up to 93" inc. Base OA at 10578' and OA -4 at 10612'.;Drill 8-1/2" production hole f/ 10693't( 1102T (3750' TVD), 334' drilled, 95.4'/hr AROP. 545 GPM, 2100 PSI, 120 RPM, 13K TO, 3-13K WOB, 11.4 ppg ECD. OA -3 at 10800' and OA -2 at 10907'. Began losing 46 BPH @ 10900'. Crossed fault #3 @ 10960' f/ OA -1 to shale below OA-4.;Adding 3 PPB Safe -Cart 10, 20, 40, 500 & 750 & slow flow to 400 GPM, 1460 PSI, 10.39 ppg ECD. Losses increased to 108 BPH @ 10973'. Slow to 385 GPM, 1440 PSI, 10.77 ppg ECD. Slow drilling due to low flow rate. Building LCM pill.;Pump 30 bbl LCM pill w/ 10 PPB Safe-Carb 40, Safe-Carb 250, Nut Plug Fine and Nut Plug Medium. Spot outside bit (732' of annulus) and allow to soak with 120 PSI (9.6 ppg EMW) MPD back pressure. Holding good pressure over 20 min. Increase to 275 PSI (10.4 ppg EMW), only lost 10 PSI over 10 min.;Drill 8-1/2" production hole U 11027' U 11 122' (3750' TVD), 95drilled, 63.34hr AROP. Begin w/ 425 GPM & no losses. Increase flow to 470 GPM, 1780 PSI, 120 RPM, 13K TO, 15K WOB. 9.1 MW, 44 vis, 10.88 ECD, 174u max gas. 153K PU / 65K SO 1105 ROT. Losses at 46 BPH, slow to 400 GPM.;LCM pill was back on time w/ 20% increase in cuttings. Currently in OA -4 with 95° inclination. Last survey @ 11051.24' MD /3753.14' TVD, 91.8° inc, 122.27" azm, 24.45' from plan, 24.44' high & 0.87' right. Drilled 18 concretions for a total thickness of 119' (4.1% of the lateral).;Losses today (midnight) to hole= 0 bbis. Total losses for interval= 0 Hauled 0 bbls H2O from 6 Mile lake for total = 2810 bbls Hauled 0 bbis H2O from B Pad creek for total = 3610 bbis Hauled 505 bbis H2O from M -Pad for total = 535 bible Hauled 0 bible heated H2O from G&I for total = 950 bbis 6/3/2019 Drill 8-1/2" production hole F/ 11122' T/11597' , 475' drilled , 797hr AROP. Begin w/ 450 GPM 10-20 BPH Losses. , 2050 PSI, 120 RPM, 13K TO, 15K WOB. 9.1 MW, 44 vis, 11.2 ECD, 149u max gas. 163K PU / 56K SO / 105 ROT.;Crossed what appeared to be a fault at 11485' . Started building up as per plan looking for the OA-4.;Continue to Drill ahead at 95 Deg F/ 11597' T/ 11767', 170' drilled, 48.6'/hr AROP. Continue adding back ground LCM to heal losses. Losses slowing. 5- 10 BPH. 500 GPM , 1900 PSI, 120 RPM, 15kTO. Slow drilling.;After not finding the OA -4 looking the logs looks like we crossed a fault at 11260 from OA -3 to OA -1 and drilled out the top of OA -1 at 11485'. Decision made to POOH to 11270 & side track low side.; Pump out of the hole F/ 11767' T/ 11218', 500 GPM. MPD shut in on connections and let build up. First stand built to 148 PSI. Less each time. last stand built to 90 PSi. ( Charged up formation);Perform side track as per DD starting at 11270' to 11290' building trough at 50 FPH, 0.71' drop observed. 500 GPM, 1863 PSI, , 120 RPM, 1 S TO. Losses at 2-5 BPH. MW 9.2 in.;DnII 8-1/2" production hole f/ 11 290'to 11502' (3705' TVD), 212' drilled, 84.87hr AROP. 550 GPM, 2240 PSI, 120 RPM, 14K TO, 5-18K WOB. 155K PU / 60K SO / 105K ROT. 9.1 MW, 44 vis, 11.3 ECD, 68u max gas.;Adding 3.5 ppb Safe -Garb 10, 20, 40, 500 & 750 background LCM w/ 20 BPH avg. losses. Drill w/ MPD choke full open, hold 140 PSI on connections. Drilling in OA -1.; Perform short trip across sidetrack point. Pump out of the hole f/ 11 502' U 11250. 550 GPM, 2200 PSI. TIH on elevators f/ 11250' U 11502'. Verified in new hole with At Bit Inclination.;Drill 8-1/2" production hole f/ 11502' U 1178T (3535' TVD), 285' drilled, 95' /hr AROP. 550 GPM, 2330 PSI, 120 RPM, 13K TO, 5-15K WOB. 165K PU 150K SO / 100K ROT. 9.1 MW, 43 vis, 11.42 ECD, 174u max gas. Pumped tandem low vis / hi vis sweep @ 11699, 35% increase 220 strokes Iale.;Adding 3-5 ppb Safe-Carb 10, 20, 40, 500 & 750 background LCM w/ 20 BPH avg. losses. Drill w/ MPD choke full open, hold 140 PSI on connections. Drilling in OA-l.;Drill 8-1/2" production hole 1111787' V 12625', 838' drilled, 139.7 ft/hr AROP. 540 GPM, 2250 PSI, 120 RPM, 14K TO, 10-17K WOB. 170 PU / NO SOW @ 12263'/ 150K ROT, 9.15 MW, 45 vis, 11.47 ECD, 195u max gas. Perform 290 new mud dilution at 12072'. ECD dropped from 11.5 to 11.1.;Adding 3-5 ppb Safe-Carb 10, 20, 40, 500 & 750 background LCM w/ 20 BPH avg. losses. Drill w/ MPD choke full open, hold 140 PSI on connections. Entered OA -2 @ 12225' and OA -3 at 12378'. Pumped tandem low vis / high vis sweeps at 12535'.;Drilled 27 concretions for a total thickness of 158' (3.6% of the lateral). Last survey @ 12478.82' MD 13766.09' TVD, 86.74' inc, 127.15' azm, 18.56' from plan, 11.01' high and 14.94' left.; Losses today to hole= 475 bbls. Total losses for interval= 475 Hauled 0 bbis H2O from 6 Mile lake for total = 2810 bbis Hauled 0 bbis H2O from B Pad creek for total = 3610 bbls Hauled 650 bbis H2O from M -Pad for total = 535 bible Hauled 0 bbis heated H2O from G&I for total = 950 bbls 6/4/2019 Drill 8-1/2" production hole V 12625' V 13250', 625 drilled, 104.16 R/hr AROP. 550 GPM, 2260 PSI, 120 RPM, 15K TO, 5-15K WOB. 9.2 MW, 46 vis, 11.53 ECD, 200u max gas. 185K PU /NO SOW/ 101K ROT. Pumped tandem low vis / hi vis sweep @ 12548', 300 stks late w/20% increase.; Encountered fault # 5 @ 13065' md, 3797" tvd which moved us from middle of OA3 to bottom of OA-4.10-13' DTN throw. Pointed up, back in OA-3 at 13246'. Initial loss rate 86 bph, slowing to 65 bph, maintain 25 ppb background LCM. MPD hold 140 psi back press during connections, full open choke drlg.;Drill 8-112" production hole f/ 13250't/13976', 726' drilled, 121 fit/hr AROP. 400 GPM, 1630 PSI, 120 RPM, 20K TO, 5-15K WOB. 9.0 MW, 45 vis, 11.5 ECD, 123u max gas. 180K PU / NO SOW / 105K ROT. MPD hold 140 psi back press during connections, full open choke drlg.;ln OA2, from 13,385', undulate to OA-1 at 13538' and level out. Encountered fault #6 at 13902' (17' DTS), point down to 87 deg Inc. 13580' MBT @ 7.5, dump and dilute w/ 290 bbs new 8.8 ppg mud. Pumped tandem low vis / hi vis sweep @ 13500', 400 stks late, 20% increase. Loss rate reducing to 24 bph.;Drill 8-1/2" production hole f/ 13976't/ 14240', 264' drilled, 44'/hr AROP. 525 GPM, 2670 PSI, 120 RPM, 19K TO, 5-15K WOB. 9.1 MW, 44 vis, 11.58 ECD, 123u max gas. 170K PU / NO SOW / 100K ROT. MPD hold 140 psi back press during connections, full open choke drlg.;Steering down w/ 86' inclination. Entered OA-1 @ 14139', 237' out of zone. Added 0.5% lubes at 14038'. Maintain 20-25 ppb LCM, 15 BPH avg loss rate. Pumped tandem low vis / high vis sweeps at 14072', back 300 strokes late with 20% increase.;Drill 8- 1/2" production hole f/ 14240't/ 15023', 783' drilled, 130.5'/hr AROP. 540 GPM, 2420 PSI, 120 RPM, 22K TO, 10-15K WOB. 9.2 MW, 42 vis, 11.64 ECD, 192u max gas. 194K PU / NO SOW 1101 K ROT. MPD hold 140 psi back press during connections, full open choke drlg.;Entered OA-2 @ 14654' & OA-3 @ 14960'. Pumped tandem low vis / high vis sweeps at 14547', back 500 strokes late with no increase. Maintain 20-25 ppb LCM, 13 BPH avg loss rate. Drilled 38 concretions for a total thickness of 203' (3.0% of the lateml).;Last survey at 14858.16' MD / 3795.44' TVD, 88.16° Inc, 125.47° mm, 6.3from plan, 1.13' high and 6.2' IeR.;Losses today to hole = 275 bbls. Total losses for interva 1= 750 Hauled 785 bbls H2O from M-Pad for total = 1320 bbls Hauled 0 bbls heated H2O from G&I for total = 950 bbls Hauled 1193 bbls cutting/liquids to MPU G&I for total= 12297 bbls 6/5/2019 Drill 8-1/2" production hole f/ 15023'V 15616, 592' drilled, 98.67hr AROP. 496 GPM, 2220 PSI, 120 RPM, 24K TO, 8-10K WOB. 9.1+ MW, 41 vis, 11.5 ECD, 120u max gas. 192K PU / NO SOW / 105K ROT. MPD hold 140 psi back press during connections, full open choke drlg.;At 15150' add 8 drums of to tork to system increasing lubes f/ 1 % to 1.5% reducing torque f/ 27k to 23k, Pumped tandem low vis / high vis sweeps at 15585', Sweep back 200 strokes late with 30% increase. Loss rate 20 bph. Drilling in OA-3.;Drill 8-1/2" production hole f/ 156161:116165% 550' drilled, 91.67hr AROP. 500 GPM, 2460 PSI, 120 RPM, 24K TO, 5-15K WOB. 9.2 MW, 42 vis, 11.77 ECD, 718u max gas. 190K PU / NO SOW / 100K ROT. MPD hold 140 psi back press during connections, full open choke drig.;Pumped tandem low vis / high vis sweeps at 16165' Begin steering up to OA-1 @ 15695', entered OA-2 @ 15869' and OA-1 @ 15986' Loss rate 8 bph.;Drill 8-1/2" production hole f/ 16165' V TD of well @ 16731', 566' drilled, 125.6/hr AROP. 460 GPM, 2140 PSI, 110 RPM, 25K TO, 8-10K WOB. 9.2 MW, 45 vis, 11.79 ECD, 126u max gas. 20 BPH losses 205K PU / NO SOW 1100 ROT.. MPD hold 140 psi back press during connections, full open choke drlg.;Dip change caused wellbore to enter OA-2 from 16417'to 16552' (135'). Steered up with 100% deflection to get back to OA-1. Observed diminishing reservoir quality and geologist called TD. TD'ed well in OA-1.;Projection to TD: 16731' MD / 3799.77' TVD, 91.86' Inc, 126.99' azm, 11.78' from plan, 10.55' low and 5.24' right. 46 concretions were drilled in the lateral, for a total thickness of 252' (2.9%). 2 plugbacks were drilled. 6 faults were crossed in the Iateral.;Obtain final survey & slow pump rates. Pump tandem low vis / high vis sweeps. 450 GPM, 2160 PSI, 110 RPM, 24K TO. Sweeps back 300 strokes late w/ 20% increase. Circulate a total of 4x bottoms up, racking back a stand every BU to 16443'. Reciprocate pipe w/ 450 GPM up & 380 GPM down for ECD <12.0.;Work back to bottom while circulating. Assembly took weight at 16548' to 16564' in OA-2 to OA-1 contact. Work through with 100 GPM and 50 RPM. Continue to circulate and work trouble area with stabilizer then simulate liner run w/o difficulty. Pumped a total of 4.6 bottoms up. 19 BPH loss average.;Begin pumping SAPP pill treatment. Pump 1st 40 bbl SAPP pill and 50 bbl seawater spacer, 7 BPM, 1340 PSI.;Losses today to hole= 375 bbls. Total losses for interval= 1125 Hauled 745 bbls H2O from M-Pad for total = 2065 bbls Hauled 0 bbls heated H2O from G&I for total = 950 bible 6/6/2019 Continue pumping SAPP pill treatment. Two more 40 bbl SAPP pills with 50 bbl seawater spacer followed by 30 bbl high vis spacer, 7 BPM, 1340 psi. Shut down, open MPD choke & bleed off pressure through open MPD choke. Flow slowed to 4 GPM, shut choke observed 43 PSI. Chase with 250 bbls seawater.;Displace wellbore w/1202 bbls 8.4+ hi vis brine w/ 4% lube, 7 bpm, 850 psi, 75 rpm, 25k torque, reciprocate pipe, divert all mud, SAPP trains and seawater to rock washer, w/ 8.5 ppg at returns MPD hold 160 psi back pressure (10.2 ppg ECD ) pump until clean brine returns.;Total losses pumping SAPP train and displacing 95 bbls. PU/SO/ROT in mud 205k/none/100k PU/SO/ROT in lub brine 183k/53k/120k Loss rate 10 bph.;Parked at 16698' Obtain SPR both pumps, shut down pumps, bleed down to 17 psi, Monitor for pressure build with MPD, built to 120 psi in 10 min and leveled off, pump 300 gpm, 950 psi 100 rpm, run back to bttm, clear ice from derrick.;BROOH f/ 16731'V 13879' pulling 5 min/stand, Seen 100 psi pressure increase f/ 14670' slow pulling speed and cleanup same to 14654', in OA-2. 500 GPM, 1670 PSI ICP / 1400 PSI FCP, 120 RPM, 15k TO. 10.3 ECD start / 10.25 ECD end.;Note: Attempt to maintain 160 PSI Dynamic w/ MPD, ECD 10.9 pulling 1 st stand. MPD chokes full open while circulating w/ 46 PSI line pressure and 280 PSI trapped on connections- reducing loss rate to 6-9 bph.;BROOH f/ 13879' V 10837' pulling 5 min/stand. 500 GPM, 1610 PSI, 120 RPM, 15K TO. Observe 100 PSI increase & ECD from 10.0 to 10.45 from 12260'-12255'& 10878'-10692'- both OA-2. Slow pulling speed. MPD chokes full open while circulating w/ 46 PSI line pressure & 280 PSI trapped on conneclions.;8 BPH loss rate average.;BROOH f/ 10837't/ 8081' pulling 5 min/stand. 500 GPM, 1450 PSI, 120 RPM, 11 K TO. MPD chokes full open while circulating w/ 46 PSI line pressure & 240 to 280 PSI trapped on connections. MW climbed from 8.5 to 8.8 ppg loss rate Inc. to 18 BPH average. Start 2nd centrifuge. 165 PU / 75K SO 1115 ROT.;Pump high viscosity pill and begin circulating 9-5/8" casing clean. 505 GPM, 1420 PSI, 100 RPM, 51K TO, 10.05 ECD. Reciprocate f/ 8081' V 7986'.;Losses today to hole= 204 bbls. Total losses for interval= 1329 Hauled 0 bbls H2O from 6 Mile lake for total = 2810 bbis Hauled 0 bbls H2O from B Pad creek for total = 3610 bbls Hauled 370 bbls H2O from M-Pad for total = 2435 bbls Hauled 0 bbls heated H2O from G&I for total = 950 bbls 6/7/2019 Finish circulating sweep around cleaning up 9 5/8" casing 506 gpm, 1420 psi, 100 rpm, 5k torque. 10% increase at sweep returns, pump additional 2 BU.;Shut down pumps and monitor flow, slowing f/ 30 gpm to 6 gpm in 15 min. Shut in and monitor pressure build f/ 17 psi to 80 psi in 15 min, bleed off 2 more times with last f/ 17 psi to 60 psi in 10 min and leveling out.;PJSM, wt up brine in active pit f/ 8.7 ppg to 8.9+ ppg and circulate around 505 gpm, 1280 psi, 100 rpm, 4k tq cap well f/ shoe up. shut down pumps, bleed off to 15 psi, shut in, built to 46 psi in 10 min, increase wt to 9.1+, with good 9.1+ in/out shut down pumps.;Monitor shut in pressure, Bleed pressure to 15 psi, shut in build to 29 psi in 15 min, bleed off, 1/4 bbl returned, shut in, build to 19 psi in 10 min, bleed off, little to no flow, shut in for additional 10 min, build f/ 15 to 16 psi, open and monitor f/ 15 min, well is static.;Remove RCD Bearing and install trip nipple, check for leaks, good. Monitor well, static.;lnstall FOSV, Hang blocks, cut and slip 66' drilling line. Service desks and TD. Continue to monitor well, static.;Pump dry job, BD TD, PJSM, TOOH from 8082' to 1728' UD 5" DP to pipe shed.; Install FOSV. Inspect saver sub - good. UD MPD bearings. Sim-ops: change micro switch on pipe skate controls.;TOOH f/ 1728' V 275' UD 5" DP to pipe shed. UD 2 joints HWDP, jars, 3 NM drill collars, 2 float subs to 83'. Read MWD tools - 100% data recovery. UD remainder of BHA. Wear observed on downhole & uphole blades of ILS and downhole blade of ALD wear sleeve. Bit graded: 1-1-CT- G-X-1-NO-TD.;Clear rig floor of BHA components. 25.5 bbls total loss for trip out of hole over 12 hours, 2.1 BPH average.;Pertonn pipe management. UD 8 stands of 5" drill pipe out of the derrick. 3.3 BPH static losses.; Losses today to hole= 125 bbls. Total losses for interval= 1454 Hauled 0 bbls H2O from 6 Mile lake for total = 2810 bbls Hauled 0 bbls H2O from B Pad creek for total = 3610 bible Hauled 90 bbls H2O from M-Pad for total = 25255 bbls Hauled 0 bbls heated H2O from G&I for total = 950 bbls 6/8/2019 Finish LID excess 12 stds 5" DP using mouse hole leaving 85 stands in derrick. Static loss rate 2 bph.;Clear pipe shed of BHA tools, load shed with 5" HWDP.;Drift, P/U and rack back 20 stands 5" HWDP in derrick using mouse hole. Static loss rate 2 bph.;R/U casing running equipment and M/U safety joint for 6-5/8" slotted liner run. Crew change.;Hold PJSM with rig & casing crew. P/U shoe joint. P/U and RIH w/ 6-5/8", 20#, L-80, Hydril 563, Slotted liner as per tally t/ 8690'. Install Centralizer every joint. M/U Tq = 7100 Wiles. Loss rate running liner 2 bph, 20 bbls total loss while running liner. At 8085', 123K PU / 85K SO.;M/U 7" x 9-5/8" SLZXP liner top packer w/ 5K PSI rupture disc sub, circulation sub set at 4K, B/U solid ball seat and orifice back pressure valve.;RIH one stand of 5" drill pipe to 8822', obtain parameters & circulate to ensure clear flow path, 2 BPM, 80 PSI, 20 RPM, 6K TQ. 128K PU / 85K SO / 102K ROT. 199 slotted and 16 solid joints, 212 total 6-5/8" x 7-3/4"centralizer free floating & 4 total 4-1/2" x 7-1/4" centralizers w/ 4 stop rings ran.;Run 6-5/8" slotted liner on 5" drill pipe out of the derrick f/ 8822't/ 10533', 83K SO. Run 6-5/8" slotted liner on 5" HWDP singles out of the pipe shed f/ 10533'tI 13654', 124K SO.;Losses today to hole= 52.5 bbls. Total losses for interval= 1506.5 Hauled 0 bbls H2O from 6 Mile lake for total = 2810 bbls Hauled 0 bbls H2O from B Pad creek for total = 3610 bible Hauled 40 bbls H2O from M -Pad for total = 2565 Jobs, Hauled 0 bbls heated H2O from G&I for total = 950 bbls 6/9/2019 Continue to Run 6-5/8" slotted liner on 5" HWDP singles out of the pipe shed f/ 13654'V 14855', 128K SO. Loss rate 1.8 bph.;Conlinue to Run 6-5/8" slotted liner w/ 20 stands 5" HWDP out of derrick f/ 14855' U 16706, M/U 2 single jts of DP, RIH and tag TD @ 16738' with liner in compression, P/U to 16731' putting liner in tension. Total losses RIH= 23.5 bbls total. PU/SO 265/136.;M/U TD, break circulation, pump 6 bpm, 980 psi, circulate DP volume. Break out single, Drop .9062" composite ball as per BOT rep, pump ball down 4 bpm 580 psi 550 stks, slow to 2 bpm, 290 psi, ball hit @ 769 stks, 80 stks early.;Pressure up to 2200 psi, see pusher tool set, hold f/ 5 min. S/O to 110k, pressure to 3470 psi, shut in at pump, w/ test pump pressure to 4500 psi, see pusher tool neutralize and shear circ sub. pressure bled to 0 psi. P/U 220k see breakover. P/U 1'to verify free.;Shut annular, test 9 5/8" x packer to 1500 psi for 10 min charted, good test. Bleed off pressure, open annular. BD lines. RID test equipment. TOL @ 8014';Switched to Completions AFE at 12:00 - see completions report for details of activity. Hilcorp Energy Company Composite Report Well Name: MP M-18 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): API #: Spud Date: Job Name: 1911313C MPU M-18 Completion Contractor AFE #: AFE $: -AifiS!ity Date _ Ops Summary 6/9/2019 Start Completions AFE at 12:00. See drilling report for details of 06:00 to 12:00 activity.,Shut annular, test 9 5/8" x packer to 1500 psi for 10 min charted, good test. Bleed off pressure, open annular. BD lines. RID test equipment. TOL @ 8014'.,TOOH 1118014' UD 2 single jts 5" DP and 5" HWDP to 1806'. Rack back 19 stands of 5" drill pipe in the derrick and UD liner running tool. Liner running tool in good condition. 22.7 bbis lost on TOOH.,Break down liner safetyjoint. Remove split bushing and install master bushings. Drain stack and pull wear bushing. Perform dummy run with T' hanger on landing joint with well head representative. Re -install wear bushing.,M/U 3-1/2" perforated orange peeled joint with 8.31" no-go to 15.84'. TIH with 5" drill pipe and tag top of liner with no-go on depth at 8014'. Wash liner tie -back w/ 5 BPM, 320 PSI then pick up out of liner. Circulate lx bottoms up while conducting PJSM for displacement. 14 BPM, 820 PSI while rotating and reciprocating - no solids observed over shakers. 3 bbls lost on TIH.,Pump 30 bbl high vis spacer then displace wellbore with new 9.15 ppg KCI/NaCL brine. 7 BPM, 410 PSI ICP, 220 PSI FCP, 50 RPM, 4K TO. Reciprocating pipe 60'. Sweep back 10 bbis late. Clean brine 70 bbis after spacer back. Perform flow check -static. Obtain new slow pump rates. UD single & B/D top drive -Slip and cut drilling Iine.,Losses today to hole= 55.5 bbis. Total losses for interval= 1562 Hauled 0 bbls H2O from 6 Mile lake for total = 2810 bbis Hauled 0 bbis H2O from B Pad creek for total = 3610 bbls Hauled 70 bbls H2O from M -Pad for total = 2565 bbis Hauled 0 bbis heated H2O from G&I for total = 950 bbl 6/10/2019 Continue to Slip and cut 73' drilling line, inspect brake bands, calibrate blocks. Static loss rate @ 1 bph.,POOH from 6007' to surface UD 5" DP to pipe shed, UD NO GO, stinger and XO. Static loss rate @ 2bph, 14.8 bbls total.,Pull wear bushing, M/U XO on FOSV. R/U handling equipment and power tongs to run 7" casing.,P/U Baker Bullet seal tie -back assembly to 15'. Run 7" 26# L-80 TXP BTC -SR casing f/ 15't/ 8025.84'. Torque to 14750 fillies with Doyon casing double stack tongs. Tag no-go on liner top (1.5' deep) w/ 5K, 150 PU / 107 SO. Close annular and pressure up to 250 PSI down annulus to verity seals landed - good test. 1.6 BPH loss rate RIH, 18.5 bbis total.,Space out liner. UD joints #202, 201 & 200. WU 14.82' and 4.83' pup joints then joint #200. M/U 7" hanger and landing joint. Land liner on hanger at 8024.43' (1.41' off no-go), 150 PU 1107 SO. R/U FOSV, circ. sub & 5' pup joint. Close annular & pressure up to 280 PSI. PIU, observe pressure bleed off through circulation ports plus additional 6".,PJSM with Doyon, M -I and Peak. Reverse circulate 167.5 bbis corrosion inhibited 9.15 ppg brine @ 4 BPM, 490 PSI. Pump through injection line to the OA taking returns out of the 7" liner. 4 bbis Iost.,Losses today to hole= 35.5 bbis. Total losses for interval= 1597 Hauled 0 bbls H2O from 6 Mile lake for total = 2810 bbls Hauled 0 bbls H2O from B Pad creek for total = 3610 bbls Hauled 75 bbls H2O from M -Pad for total = 2640 bbls Hauled 0 bbis heated H2O from G&I for total = 950 bbls 6/11/2019 Line up and reverse circ 80 bbis diesel from vac truck 4 bpm, 690 psi freeze protecting 9 5/8" z 7" annulus to 2500', Land hanger w/ 67k Hanger -Bleed down to cellar and verify seals engaged. Good. Back side dead. Open annular & drain stack. RID landing joint.. M/U Pack off running tool on jt of 5" HWDP. RIH & set pack off. RILD as per Wellhead rep. UD running tool. Test Void to 500/5000 psi , 5 min./10 min - good., R/U test pump, with diesel Test 7" X 9-5/8" annulus to 1100 psi for 30 charted min. Good. Bleed of pressure, RID test equipment. BD kill and injection Iines.,Clearrig floor. R/U to run 3 1/2" jet pump completion, 3.5" handling equipment, Doyon double stack power tongs, tech wire spool and sheave, cannon clamps. Crew change. Static loss rate at 2 bph.,PJSM, M/U 3- 1/2" pup joint w/ wireline entry guide, 40 joints of 3-1/2" 9.3# L-80 EUE tubing, HES XN nipple assy, HES 3-1/2"x7" retrievable packer, HES X nipple assy and SLB sliding sleeve and gauges to 1344'. Torque to 3100 fNlbs with Doyon casing double stack tongs. Terminate TEC wire and pressure test to 5000 PSI - good test Loss Rate @ 1.7 bph.,Continue to run 3-1/2" 9.3# L-80 EUE tubing f/ 1344' t/ 8013' as per tally. Torque to 3100 fill with Doyon casing double stack tongs. Install Cannon clamps at every connection. Total 212 Cannon clamps, 5 half clamps & 2 centralizer clamps. Loss Rate Continues at 1.7 BPH.,C/O elevators & PIU 5" drill pipe landing joint. M/U XO subs & Cameron 11"x3-1/2" tubing hanger. Perform TEC wire penetrations through hanger. Blow down lines. Land 3- 1/2" completion on hanger. 80K PU, 64K SO, 24K on hanger.,Run in lock down screws. Drop ball (1.31") & rod. R/U circulating head, hoses & chart recorder., Pressure up to 3675 PSI on the tubing. Set packer & test tubing for 30 min. Bleed tubing to 2100 PSI. Pressure up to 3700 PSI on the IA & test casing for 30 min. Tubing climbed to 2700 PSI due to compression. Bleed tubing off, shear valve in GLM @ 3102'.,UD landing jt. Install BPV and test t/ 500 psi. Start cleaning rig floor while prep to nipple down BOP stack.,Remove MPD trip nipple & kill line. Nipple down BOP stack. SimOps: Continue clear rig floor of completion running equipment. Cleaning Mud Pits., Losses today to hole= 31 bbls. Total losses for interval= 1628 Hauled 0 bbis H2O from 6 Mile lake for total = 2810 bbls Hauled 0 bbis H2O from B Pad creek for total = 3610 bbis Hauled 80 bbis H2O from M -Pad for total = 2720 bbis Hauled 0 bbis heated H2O from G&I for total = 950 bbls Hauled 260 bbis cutting/liquids to MPU G&I for total= 17214 bbls 6/12/2019 Pull mouse hole, N/D BOPE. Install dart in BPV. Clear rig floor, Load out tbg handling and SLB equipment.,Prep wellhead, terminate Tech wire thru adaptor flange. Install and N/U tree. Continue to clear rig floor. Finish cleaning pits. Submit 24 hr notification to AOGCC M-20 diverter test @ 08:00,Test hanger void to 250 low f/ 5 min, 5000 psi hi f/ 10 min. Fill tree with diesel, Test tree to 250/ 5000 psi 5 min ea, charted. Pull dart f/ BPV. Perform final readings for jet pump DH gauges at WH. upper 1627.66 psi, temp 69.61 deg. Lower 1631.14 psi, temp 69.82 deg., Freeze protect I/A x tbg to 3102' with 111 bbls diesel pumping down tbg with returns out I/A. Swap from highline to Gen power @ 11:00. Rig Released @ 12:OO.,Flush pumps & rig down lines. Install gauges on Wellhead. Prep rig floor for move, blow down buildings, remove remaining brine from pits. Clean and secure well. Skid Rig floor into moving position,See M-20 for details Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-18 500292363200 Sperry Drilling Definitive Survey Report 07 June, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU MI -18 Project: Milne Point TVD Reference: MPU M-18 Actual IRKS @ 59.12usft Site: M Pt Moose Pad MD Reference: MPU M-18 Actual RKB @ 59.12usft Well: MPU M-18 North Reference: True Welibore: MPU M-18 Survey Calculation Method: Minimum Curvature Design: MPU M-18 Database: NORTH US+CANADA koject Milne Point, ACT, MILNE POINT lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point nap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-18 Well Position +NIS +EI -W Position Uncertainty Wellbore MPU M-18 Magnetics Model Name 0.00 usft Northing: 6,027,765.61 usfl 0.00 usft Easting: 533,603.87 usfl 0.00 usft Wellhead Elevation: usfl Sample Date Declination (I BGGM2018 6/412019 16.61 Design MPU M-18 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +N/ -S (usft) (usfl) 34.42 0.00 Latitude: 70° 29'12.7926 N Longitude: 149° 43'31.2401 W Ground Level: 24.70 usft Dip Angie Field Strength (`) (nT) 80.96 57,424.29988807 Tie On Depth: 11,241.78 +E1 -W Direction (usft) (') 0.00 125.08 Survey Program Date 6/612019 From To (usft) (usfl) Survey (Wellbore) Tool Name Description Survey Date 164.12 8,107.51 MPU M-18PB1 MWD+IFR2+MS+Sag(1)2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/17/2019 8,200.93 9,910.38 MPU M-18PB1 MWD+IFR2+MS+sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 06/03/2019 9,990.00 11,241.78 MPU M-18PB2 MWD+IFR2+MS+sag (3) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 06/03/2019 11,270.00 16,661.06 MPU M-18 MWD+IFR2+MS+Sag (4) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 06/04/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (1) (1) (usfl) (usft) (usfl) (usfl) (ft) (ft) (°110(y) (ft) Survey Tool Name 34.42 0.00 0.00 34.42 -24.70 0.00 0.00 6,027,765.61 533,603.87 0.00 0.00 UNDEFINED 164.12 0.63 233.04 164.12 105.00 -0.43 -0.57 6,027,765.18 533,603.30 0.49 -0.22 2_MWD+IFR2+MS+Sag(1) 228.13 0.77 236.57 228.12 169.00 -0.88 -1.21 6,027,764.73 533,602.66 0.23 -0.49 2_MWD+IFR2+MS+Sag(1) 320.86 1.15 233.69 320.84 261.72 -1.77 -2.48 6,027,763.83 533,601.40 0.41 -1.01 2_MWD+IFR2+MS+Sag(1) 413.63 0.42 285.16 413.60 354.48 -2.23 -3.56 6,027,763.36 533,600.32 1.02 -1.63 2_MWD+IFR2+MS+Sag(1) 508.35 1.19 173.57 508.31 449.19 -3.12 -3.78 6,027,762.47 533,600.10 1.48 -1.30 2_MWD+IFR2+MS+Sag(1) 600.39 5.14 161.73 600.20 541.08 -7.99 -2.38 6,027,757.61 533,601.52 4.33 2.64 2_MWD+IFR2+MS+Sag(1) 693.23 8.83 157.89 692.33 633.21 -18.54 1.60 6,027,747.08 533,605.56 4.00 11.97 2_MWD+IFR2+MS+Sag(1) 788.27 13.36 158.00 785.57 726.45 -35.49 8.47 6,027,730.16 533,612.50 4.77 27.33 2_MWD+IFR2+MS+Sag(1) 881.76 17.72 160.63 875.62 816.50 -58.94 17.24 6,027,706.76 533,621.37 4.72 47.98 2_MWD+IFR2+MS+Sag(1) 978.32 21.30 162.90 966.63 907.51 -89.57 27.27 6,027,676.17 533,631.54 3.79 73.80 2_MWD+IFR2+MS+Sag(1) 6/72019 1:00.01 PM Page 2 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-18 Wellbore: MPU M-18 Design: MPU M-18 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing (usft) (') (') (usft) (usft) (usft) (usft) (ft) 1,073.27 24.70 163.70 1,054.01 994.89 -125.11 37.91 6,027,640.69 1,166.03 28.70 165.29 1,136.87 1,077.75 -165.27 49.01 6,027,600.58 1,261.82 33.09 166.06 1,219.05 1,159.93 -212.92 61.16 6,027,552.99 1,355.20 35.74 167.74 1,296.08 1,236.96 -264.32 73.09 6,027,501.65 1,453.28 38.48 168.57 1,374.29 1,315.17 -322.23 85.22 6,027,443.80 1,548.91 41.19 166.89 1,447.72 1,388.60 -382.07 98.27 6,027,384.02 1,643.82 44.35 165.00 1,517.38 1,458.26 -444.57 113.94 6,027,321.60 1,736.64 49.58 163.45 1,580.71 1,521.59 -509.83 132.42 6,027,256.44 1,832.69 52.77 163.31 1,640.92 1,581.80 -581.52 153.82 6,027,184.85 1,927.74 57.39 162.96 1,695.31 1,636.19 -656.08 176.43 6,027,110.40 2,023.82 63.05 161.79 1,743.01 1,683.89 -735.52 201.69 6,027,031.09 2,118.64 66.96 162.85 1,783.07 1,723.95 -817.38 227.78 6,026,949.34 2,213.65 68.76 163.66 1,818.88 1,759.76 -901.65 253.13 6,026,865.20 2,309.25 69.69 165.45 1,852.79 1,793.67 -987.80 276.92 6,026,779.16 2,404.74 69.49 165.05 1,886.09 1,826.97 -1,074.35 299.71 6,026,692.73 2,499.30 69.70 164.97 1,919.06 1,859.94 -1,159.96 322.63 6,026,607.23 2,593.72 69.17 165.63 1,952.22 1,893.10 -1,245.47 345.07 6,026,521.84 2,689.41 70.41 165.74 1,985.28 1,926.16 -1,332.48 367.27 6,026,434.94 2,784.18 69.43 165.54 2,017.82 1,958.70 -1,418.71 389.34 6,026,348.82 2,879.83 69.78 164.03 2,051.15 1,992.03 -1,505.21 412.87 6,026,262.43 2,974.20 69.29 164.26 2,084.15 2,025.03 -1,590.26 437.03 6,026,177.49 3,069.19 69.55 162.91 2,117.54 2,058.42 -1,675.56 462.16 6,026,092.32 3,164.07 69.62 163.70 2,150.64 2,091.52 -1,760.74 487.70 6,026,007.27 3,258.32 68.99 164.33 2,183.94 2,124.82 -1,845.49 511.98 6,025,922.63 3,353.64 67.46 164.78 2,219.30 2,160.18 -1,930.81 535.56 6,025,837.43 3,449.51 68.77 164.36 2,255.04 2,195.92 -2,016.56 559.23 6,025,751.79 3,544.38 69.89 164.31 2,288.52 2,229.40 -2,102.03 583.20 6,025,666.44 3,639.31 69.75 165.47 2,321.27 2,262.15 -2,188.05 606.42 6,025,580.54 3,735.11 70.62 165.81 2,353.75 2,294.63 -2,275.36 628.77 6,025,493.34 3,829.24 70.74 164.38 2,384.89 2,325.77 -2,361.20 651.62 6,025,407.61 3,924.40 68.90 163.55 2,417.72 2,358.60 -2,447.04 676.29 6,025,321.89 4,018.80 67.86 163.50 2,452.50 2,393.38 -2,531.19 701.18 6,025,237.86 4,113.73 69.30 163.84 2,487.17 2,428.05 -2,616.00 726.02 6,025,153.18 4,209.64 70.79 164.13 2,519.90 2,460.78 -2,702.65 750.89 6,025,066.65 4,305.45 71.60 163.15 2,550.78 2,491.66 -2,789.67 776.44 6,024,979.75 4,400.02 69.23 162.44 2,582.48 2,523.36 -2,874.78 802.79 6,024,894.77 4,495.37 70.67 161.82 2,615.17 2,556.05 -2,960.02 830.28 6,024,809.66 4,590.52 68.95 162.19 2,648.01 2,588.89 -3,044.95 857.87 6,024,724.86 4,686.01 66.82 162.61 2,683.96 2,624.84 -3,129.27 884.62 6,024,640.68 4,781.07 66.62 163.43 2,721.53 2,662.41 -3,212.78 910.12 6,024,557.29 6172019 1:00.01PM Page 3 Well MPU M-18 MPU M-18 Actual RKB @ 59.12usft MPU M-18 Actual RKB @ 59.12usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°/100') (ft) Survey Tool Name 533,642.34 3.60 102.93 2_MWD+IFR2+MS+Sag(1) 533,653.62 4.38 135.09 2_MWD+IFR2+MS+Sag(1) 533,665.98 4.60 172.42 2_MWD+IFR2+MS+Sag(1) 533,678.15 3.01 211.72 2_MWD+IFR2+MS+Sag(1) 533,690.54 2.84 254.94 2_MWD+IFR2+MS+Sag(1) 533,703.85 3.05 300.00 2_MWD+IFR2+MS+Sag (1) 533,719.81 3.59 348.75 2_MWD+IFR2+MS+Sag(1) 533,738.58 5.76 401.37 2_MWD+IFR2+MS+Sag(1) 533,760.30 3.32 460.09 2_MWD+IFR2+MS+Sag(1) 533,783.25 4.87 521.45 2_MWD+IFR2+MS+Sag(1) 533,808.86 5.98 587.77 2_MWD+IFR2+MS+Sag(1) 533,835.31 4.25 656.17 2_MWD+IFR2+MS+Sag(1) 533,861.04 2.05 725.34 2 MWD+IFR2+MS+Sag(1) 533,885.23 2.00 794.33 2_MWD+IFR2+MS+Sag(1) 533,908.40 0.44 862.72 2_MWD+IFR2+MS+Sag(1) 533,931.71 0.24 930.68 2_MWD+IFR2+MS+Sag(1) 533,954.53 0.86 998.18 2_MWD+IFR2+MS+Sag(1) 533,977.12 1.30 1,066.36 2_MWD+IFR2+MS+Sag(1) 533,999.58 1.05 1,133.98 2_MWD+IFR2+MS+Sag(1) 534,023.50 1.52 1,202.95 2_MWD+IFR2+MS+Sag(1) 534,048.04 0.57 1,271.60 2_MWD+IFR2+MS+Sag (1) 534,073.55 1.36 1,341.19 2_MWD+IFR2+MS+Sag(1) 534,099.48 0.78 1,411.04 2_MWD+IFR2+MS+Sag (1) 534,124.14 0.92 1,479.62 2_MWD+IFR2+MS+Sag(1) 534,148.09 1.66 1,547.95 2_MWD+IFR2+MS+Sag(1) 534,172.15 1.43 1,616.60 2_MWD+IFR2+MS+Sag(1) 534,196.50 1.18 1,685.34 2_MWD+IFR2+MS+Sag(1) 534,220.11 1.16 1,753.78 2_MWD+IFR2+MS+Sag(1) 534,242.86 0.97 1,822.25 2_MWD+IFR2+MS+Sag(1) 534,266.09 1.44 1,890.28 2_MWD+IFR2+MS+Sag(1) 534,291.14 2.10 1,959.80 2_MWD+IFR2+MS+Sag(1) 534,316.41 1.10 2,028.53 2_MWD+IFR2+MS+Sag (1) 534,341.63 1.55 2,097.61 2_MWD+IFR2+MS+Sag(1) 534,366.89 1.58 2,167.76 2_MWD+IFR2+MS+Sag(1) 534,392.83 1.29 2,238.68 2_MWD+IFR2+MS+Sag (1) 534,419.56 2.60 2,309.15 2_MWD+IFR2+MS+Sag(1) 534,447.43 1.63 2,380.64 2_MWD+IFR2+MS+Sag(1) 534,475.40 1.84 2,452.03 2 MWD+IFR2+MS+Sag(1) 534,502.53 2.27 2,522.38 2_MWD+IFR2+MS+Sag(1) 534,528.40 0.82 2,591.24 2_MWD+IFR2+MS+Sag(1) COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU MI -18 Project: Milne Point TVD Reference: MPU M-18 Actual RKB @ 59.12usft Site: M Pt Moose Pad MD Reference: MPU M-18 Actual RKB @ 59.12usft Well: MPU M-18 North Reference: - True Wellbore: MPU M-18 Survey Calculation Method: Minimum Curvature Design: MPU M-18 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (111001) (ft) Survey Tool Name 4,876.39 69.02 164.38 2,757.51 2,698.39 -3,297.59 934.58 6,024,472.61 534,553.24 2.68 2,660.00 2_MWD+IFR2+MS+Sag(1) 4,971.39 6909 164.36 2,791.47 2,732.35 -3,383.03 958.48 6,024,387.28 534,577.53 0.08 2,728.67 2_MWD+IFR2+MS+Sag(1) 5,066.98 70.35 165.28 2,824.60 2,765.48 -3,469.56 981.96 6,024,300.86 534,601.40 1.60 2,797.61 2_MWD+IFR2+MS+Sag(1) 5,162.02 70.29 165.04 2,856.61 2,797.49 -3,556.06 1,004.88 6,024,214.47 534,624.70 0.25 2,866.08 2_MWD+IFR2+MS+Sag(1) 5,256.79 69.24 165.80 2,889.39 2,830.27 5,642.12 1,027.26 6,024,128.53 534,647.48 1.34 2,933.86 2_MWD+IFR2+MS+Sag (1) 5,351.88 71.47 165.95 2,921.35 2,862.23 -3,728.96 1,049.12 6,024,041.79 534,669.72 2.35 3,001.65 2_MWD+IFR2+MS+Sag (1) 5,447.58 72.10 166.58 2,951.27 2,892.15 -3,817.27 1,070.70 6,023,953.60 534,691.70 0.91 3,070.06 2_MWD+IFR2+MS+Sag(1) 5,542.87 71.93 167.36 2,980.69 2,921.57 -3,905.57 1,091.13 6,023,865.40 534,712.53 0.80 3,137.53 2_MWD+IFR2+MS+Sag(1) 5,638.19 72.58 165.32 3,009.74 2,950.62 -3,993.78 1,112.57 6,023,777.30 534,734.37 2.15 3,205.78 2_MWD+IFR2+MS+Sag(1) 5,732.84 71.14 165.06 3,039.21 2,980.09 4,080.73 1,135.56 6,023,690.45 534,757.75 1.54 3,274.57 2_MWD+IFR2+MS+Sag(1) 5,829.48 68.77 164.71 3,072.33 3,013.21 4,168.37 1,159.23 6,023,602.93 534,781.81 2.48 3,344.30 2_MWD+IFR2+MS+Sag(1) 5,924.62 69.58 164.99 3,106.16 3,047.04 4,254.20 1,182.47 6,023,517.21 534,805.43 0.89 3,412.65 2_MWD+IFR2+MS+Sag(1) 6,019.97 67.76 165.20 3,140.84 3,081.72 -4,340.03 1,205.32 6,023,431.50 534,828.67 1.92 3,480.67 2_MWD+IFR2+MS+Sag(1) 6,114.44 67.10 163.47 3,177.10 3,117.98 -4,42402 1,228.87 6,023,347.62 534,852.59 1.83 3,548.22 2_MWD+IFR2+MS+Sag(1) 6,208.68 68.43 163.60 3,212.76 3,153.64 -4,507.67 1,253.59 6,023,264.09 534,877.69 1.42 3,616.53 2_MWD+IFR2+MS+Sag(1) 6,304.35 67.43 163.10 3,248.71 3,189.59 4,592.62 1,278.99 6,023,179.27 534,903.47 1.15 3,686.13 2_MWD+IFR2+MS+Sag(1) 6,399.44 67.44 162.96 3,285.20 3,226.08 4,676.60 1,304.62 6,023,095.41 534,929.48 0.14 3,755.37 2_MWD+IFR2+MS+Sag(1) 6,494.73 69.37 162.72 3,320.26 3,261.14 -4,761.26 1,330.76 6,023,010.89 534,956.00 2.04 3,825.42 2_MWD+IFR2+MS+Sag(1) 6,589.48 68.17 162.74 3,354.57 3,295.45 4,845.59 1,356.98 6,022,926.68 534,982.60 1.27 3,895.34 2_MWD+IFR2+MS+Sag(1) 6,684.72 66.44 163.64 3,391.32 3,332.20 -4,929.70 1,382.40 6,022,842.70 535,008.39 2.01 3,964.48 2_MWD+IFR2+MS+Sag(1) 6,779.98 68.42 164.82 3,427.88 3,368.76 -5,014.35 1,406.30 6,022,758.16 535,032.67 2.37 4,032.69 2_MWD+IFR2+MS+Sag(1) 6,874.67 72.82 162.88 3,459.30 3,400.18 -5,100.11 1,431.15 6,022,672.52 535,057.91 5.03 4,102.32 2_MWD+IFR2+MS+Sag(1) 6,970.24 73.85 159.70 3,486.71 3,427.59 -5,186.82 1,460.52 6,022,585.96 535,087.67 3.36 4,176.18 2_MWD+IFR2+MS+Sag(1) 7,065.15 73.01 157.01 3,513.78 3,454.66 -5,271.36 1,494.07 6,022,501.57 535,121.59 2.86 4,252.23 2_MWD+IFR2+MS+Sag(1) 7,161.17 74.56 153.32 3,540.60 3,481.48 -5,355.01 1,532.80 6,022,418.11 535,160.69 4.03 4,331.99 2_MWD+IFR2+MS+Sag(1) 7,255.19 75.27 150.87 3,565.07 3,505.95 5,435.23 1,575.28 6,022,338.09 535,203.54 2.63 4,412.86 2_MWD+IFR2+MS+Sag (1) 7,351.21 77.54 146.59 3,587.65 3,528.53 -5,514.96 1,623.72 6,022,258.58 535,252.33 4.94 4,498.33 2_MWD+IFR2+MS+Sag(1) 7,443.28 78.60 141.58 3,606.70 3,547.58 -5,587.89 1,676.55 6,022,185.90 535,305.48 5.45 4,583.48 2_MWD+IFR2+MS+Sag(1) 7,540.79 79.51 137.89 3,625.22 3,566.10 -5,660.92 1,738.42 6,022,113.16 535,367.68 3.83 4,676.08 2_MWD+IFR2+MS+Sag(1) 7,636.36 79.25 132.84 3,642.84 3,583.72 -5,727.74 1,804.39 6,022,046.64 535,433.94 5.20 4,768.47 2_MWD+IFR2+MS+Sag(1) 7,732.26 77.61 127.72 3,662.09 3,602.97 -5,788.47 1,876.03 6,021,986.24 535,505.85 5.50 4,862.00 2_MWD+IFR2+MS+Sag(1) 7,827.17 75.51 125.72 3,684.15 3,625.03 -5,843.66 1,950.01 6,021,931.39 535,580.07 3.02 4,954.26 2_MWD+IFR2+MS+Sag(1) 7,922.47 78.13 124.22 3,705.88 3,646.76 5,896.84 2,026.04 6,021,878.57 535,656.33 3.15 5,047.04 2_MWD+IFR2+MS+Sag(1) 8,017.15 82.89 123.49 3,721.48 3,662.36 -5,948.84 2,103.57 6,021,826.92 535,734.09 5.08 5,140.38 2_MWD+IFR2+MS+Sag(1) 8,107.51 90.68 124.69 3,726.55 3,667.43 -5,999.37 2,178.23 6,021,776.73 535,808.96 8.72 5,230.51 2_MWD+IFR2+MS+Sag(1) 8,200.93 91.06 125.48 3,725.13 3,666.01 -6,053.06 2,254.66 6,021,723.40 535,885.63 0.94 5,323.92 2_MWD+IFR2+MS+Sag (2) 8,296.65 88.15 124.03 3,725.79 3,666.67 -6,107.62 2,333.29 6,021,669.20 535,964.50 3.40 5,419.62 2_MWD+IFR2+MS+Sag (2) 8,391.43 86.68 124.51 3,730.06 3,670.94 -6,160.93 2,411.54 6,021,616.24 536,042.98 1.63 5,514.29 2_MWD+IFR2+MS+Sag (2) 8,482.98 86.68 123.75 3,735.36 3,676.24 -6,212.21 2,487.19 6,021,565.31 536,118.86 0.83 5,605.67 2_MWD+IFR2+MS+Sag (2) 8,578.98 87.73 125.25 3,740.05 3,680.93 -6,266.52 2,566.21 6,021,511.37 536,198.11 1.91 5,701.55 2_MWD+IFR2+MS+Sag(2) 6/72019 1:00:01 PM Page 4 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-18 Wellbore: MPU M-18 Design: MPU M-18 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +NI -S +EI -W Northing (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) 8,676.33 91.38 129.73 3,740.80 3,681.68 -6,325.74 2,643.42 6,021,452.50 8,770.75 90.07 129.85 3,739.61 3,680.49 -6,386.16 2,715.96 6,021,392.41 8,867.27 91.19 127.78 3,738.55 3,679.43 -6,446.66 2,791.16 6,021,332.27 8,962.03 88.66 125.07 3,738.67 3,679.55 -6,502.91 2,867.39 6,021,276.36 9,056.53 87.91 123.29 3,741.50 3,682.38 -6,555.98 2,945.53 6,021,223.66 9,151.62 86.49 122.31 3,746.14 3,687.02 -6,607.42 3,025.36 6,021,172.57 9,246.25 88.16 123.51 3,750.56 3,691.44 -6,658.78 3,104.71 6,021,121.58 9,341.19 90.01 126.19 3,752.08 3,692.96 -6,713.02 3,182.61 6,021,067.70 9,436.04 90.26 126.51 3,751.85 3,692.73 -6,769.24 3,259.00 6,021,011.84 9529.82 88.90 126.43 3,752.54 3,693.42 -6,824.98 3,334.41 6,020,956.44 9,626.24 87.91 125.85 3,755.22 3,696.10 -6,881.82 3,412.25 6,020,899.96 9,721.05 88.16 124.23 3,758.47 3,699.35 -6,936.22 3,489.82 6,020,845.91 9,816.23 88.16 125.21 3,761.53 3,702.41 -6,990.40 3,568.01 6,020,792.09 9,910.38 89.34 123.72 3,763.58 3,704.46 -7,043.67 3,645.62 6,020,739.18 9,990.00 92.54 123.27 3,762.28 3,703.16 -7,087.59 3,712.00 6,020,695.56 10,006.32 91.12 122.72 3,761.75 3,702.63 -7,096.48 3,725.68 6,020,686.74 10,101.54 89.58 124.75 3,761.17 3,702.05 -7,149.35 3,804.86 6,020,634.23 10,197.13 89.89 125.03 3,761.61 3,702.49 -7,204.03 3,883.26 6,020,579.91 10,292.85 87.66 124.89 3,763.66 3,704.54 -7,258.86 3,961.69 6,020,525.44 10,385.96 86.55 125.36 3,768.36 3,709.24 -7,312.36 4,037.74 6,020,472.29 10,482.16 88.41 126.52 3,772.59 3,713.47 -7,368.77 4,115.55 6,020,416.24 10,576.99 92.12 127.39 3,772.15 3,713.03 -7,425.77 4,191.31 6,020,359.59 10,672.12 92.98 127.39 3,767.92 3,708.80 -7,483.48 4,266.82 6,020,302.23 10,767.40 92.73 125.59 3,763.18 3,704.06 -7,540.06 4,343.33 6,020,245.99 10,862.53 92.86 122.93 3,758.54 3,699.42 -7,593.55 4,421.85 6,020,192.87 10,956.72 90.93 122.02 3,755.42 3,696.30 -7,644.09 4,501.26 6,020,142.69 11,051.24 91.80 122.27 3,753.17 3,694.05 -7,694.37 4,581.27 6,020,092.78 11,146.89 95.59 124.20 3,747.01 3,687.89 -7,746.67 4,661.09 6,020,040.84 11,241.78 94.09 125.52 3,739.00 3,679.88 -7,800.71 4,738.67 6,019,987.16 11,270.00 93.61 125.45 3,737.10 3,677.98 -7,817.05 4,761.60 6,019,970.92 11,337.35 90.62 125.29 3,734.62 3,675.50 -7,856.01 4,816.47 6,019,932.22 11,430.99 89.09 126.12 3,734.86 3,675.74 -7,910.66 4,892.51 6,019,877.92 11,527.41 89.77 127.95 3,735.82 3,676.70 -7,968.72 4,969.47 6,019,820.21 11,622.69 89.95 127.84 3,736.05 3,676.93 -8,027.25 5,044.66 6,019,762.03 11,717.62 90.20 124.90 3,735.92 3,676.80 -8,083.53 5,121.09 6,019,706.09 11,812.52 89.15 122.12 3,736.46 3,677.34 -8,135.92 5,200.20 6,019,654.07 11,907.88 88.65 120.73 3,738.29 3,679.17 -8,185.63 5,281.56 6,019,604.74 12,003.41 88.72 122.79 3,740.49 3,681.37 -8,235.89 5,362.76 6,019,554.84 12,098.11 85.99 124.12 3,744.86 3,685.74 -8,288.04 5,441.68 6,019,503.06 12,193.00 88.23 125.39 3,749.64 3,690.52 -8,342.06 5,519.53 6,019,449.40 Well MPU M-18 MPU M-18 Actual RKB @ 59.12usft MPU M-18 Actual RKB @ 59.12usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°11001) (ft) Survey Tool Name 536,275.56 5.94 5,798.77 2_MWD+IFR2+MS+Sag (2) 536,348.39 1.39 5,892.86 2_MWD+IFR2+MS+Sag (2) 536,423.85 2.44 5,989.16 2_MWD+IFR2+MS+Sag(2) 536,500.33 3.91 6,083.88 2_MWD+IFR2+MS+Sag(2) 536,578.70 2.04 6,178.32 2_MWD+IFR2+MS+Sag(2) 536,658.75 1.81 6,273.22 2_MWD+IFR2+MS+Sag(2) 536,738.33 2.17 6,367.68 2_MWD+IFR2+MS+Sag (2) 536,816.46 3.43 6,462.59 2_MWD+IFR2+MS+Sag(2) 536,893.10 0.43 6,557.42 2_MWD+IFR2+MS+Sag (2) 536,968.75 1.45 6,651.16 2_MWD+IFR2+MS+Sag(2) 537,046.84 1.19 6,747.53 2_MWD+IFR2+MS+Sag (2) 537,124.65 1.73 6,842.28 2_MWD+IFR2+MS+Sag (2) 537,203.08 1.03 6,937.41 2_MWD+IFR2+MS+Sag (2) 537,280.91 2.02 7,031.53 2_MWD+IFR2+MS+Sag (2) 537,347.48 4.07 7,111.09 2_MWD+IFR2+MS+Sag (3) 537,361.20 9.35 7,127.39 2_MWD+IFR2+MS+Sag(3) 537,440.61 2.68 7,222.58 2_MWD+IFR2+MS+Sag (3) 537,519.26 0.44 7,318.17 2_MWD+IFR2+MS+Sag (3) 537,597.92 2.33 7,413.86 2_MWD+IFR2+MS+Sag (3) 537,674.21 1.29 7,506.85 2_MWD+IFR2+MS+Sag(3) 537,752.26 2.28 7,602.94 2_MWD+IFR2+MS+Sag(3) 537,828.28 4.02 7,697.70 2_MWD+IFR2+MS+Sag(3) 537,904.04 0.90 7,792.66 2_MWD+IFR2+MS+Sag(3) 537,980.79 1.90 7,887.78 2_MWD+IFR2+MS+Sag (3) 538,059.54 2.80 7,982.78 2_MWD+IFR2+MS+Sag(3) 538,139.18 2.27 8,076.82 2_MWD+IFR2+MS+Sag(3) 538,219.40 0.96 8,171.19 2_MWD+IFR2+MS+Sag(3) 538,299.45 4.44 8,266.57 2_MWD+IFR2+MS+Sag(3) 538,377.27 2.10 8,361.11 2_MWD+IFR2+MS+Sag (3) 538,400.27 1.72 8,389.27 2_MWD+IFR2+MS+Sag (4) 538,455.31 4.45 8,456.56 2_MWD+IFR2+MS+Sag(4) 538,531.59 1.86 8,550.19 2_MWD+IFR2+MS+Sag(4) 538,608.80 2.02 8,646.55 2_MWD+IFR2+MS+Sag(4) 538,684.25 0.22 8,741.71 2 MWD+IFR2+MS+Sag(4) 538,760.92 3.11 8,836.61 2_MWD+IFR2+MS+Sag (4) 538,840.27 3.13 8,931.46 2_MWD+IFR2+MS+Sag (4) 538,921.84 1.55 9,026.61 2_MWD+IFR2+MS+Sag (4) 539,003.25 2.16 9,121.95 2M_WD+IFR2+MS+Sag(4) 539,082.40 3.21 9,216.50 2_MWD+IFR2+MS+Sag(4) 539,160.49 2.71 9,311.26 2_MWD+IFR2+MS+Sag(4) 6/72019 1:00:01PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-18 Project: Milne Point TVD Reference: MPU M-18 Actual RKB @ 59.12usft Site: M Pt Moose Pad MD Reference: MPU M-18 Actual RKB @ 59.12usft Well: MPU M-18 North Reference: True Wellbore: MPU M-18 Survey Calculation Method: Minimum Curvature Design: MPU M-18 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 12,287.80 87.05 125.05 3,753.54 3,694.42 -8,396.69 5,596.91 6,019,395.13 539,238.11 1.30 9,405.97 2_MWD+IFR2+MS+Sag(4) 12,383.60 85.57 125.23 3,759.71 3,700.59 -8,451.71 5,675.09 6,019,340.46 539,316.52 1.56 9,501.57 2_MWD+IFR2+MS+Sag(4) 12,478.82 86.74 127.15 3,766.09 3,706.97 -8,507.80 5,751.76 6,019,284.72 539,393.44 2.36 9,596.55 2_MWD+IFR2+MS+Sag (4) 12,573.26 89.65 128.58 3,769.07 3,709.95 -8,565.74 5,826.27 6,019,227.13 539,468.20 3.43 9,690.82 2_MWD+IFR2+MS+Sag(4) 12,668.57 92.37 129.73 3,767.39 3,708.27 -8,625.90 5,900.15 6,019,167.31 539,542.35 3.10 9,785.87 2_MWD+IFR2+MS+Sag (4) 12,764.21 90.01 128.35 3,765.40 3,706.28 -8,686.12 5,974.41 6,019,107.43 539,616.88 2.86 9,881.25 2_MWD+IFR2+MS+Sag (4) 12,859.89 89.89 126.97 3,765.49 3,706.37 -8,744.58 6,050.16 6,019,049.32 539,692.88 1.45 9,976.83 2_MWD+IFR2+MS+Sag(4) 12,954.98 89.39 126.74 3,766.08 3,706.96 -8,801.61 6,126.24 6,018,992.64 539,769.21 0.58 10,071.87 2_MWD+IFR2+MS+Sag(4) 13,050.06 89.52 126.25 3,766.99 3,707.87 -8,850.16 6,202.68 6,018,936.44 539,845.89 0.53 10,166.92 2_MWD+IFR2+MS+Sag(4) 13,145.40 90.63 124.60 3,766.86 3,707.74 -8,913.42 6,280.36 6,018,881.54 539,923.82 2.09 10,262.25 2_MWD+IFR2+MS+Sag(4) 13,240.88 92.61 123.89 3,764.16 3,705.04 -8,967.12 6,359.25 6,018,828.19 540,002.94 2.20 10,357.68 2_MWD+IFR2+MS+Sag (4) 13,335.73 92.85 123.63 3,759.65 3,700.53 -9,019.77 6,438.02 6,018,775.91 540,081.94 0.37 10,452.40 2_MWD+IFR2+MS+Sag (4) 13,430.95 92.73 123.82 3,755.01 3,695.89 -9,072.58 6,517.12 6,018,723.47 540,161.27 0.24 10,547.48 2_MWD+IFR2+MS+Sag(4) 13,525.91 92.05 123.98 3,751.05 3,691.93 -9,125.49 6,595.87 6,018,670.91 540,240.25 0.74 10,642.33 2_MWD+IFR2+MS+Sag (4) 13,621.56 92.42 124.49 3,747.32 3,688.20 -9,179.26 6,674.89 6,018,617.50 540,319.50 0.66 10,737.90 2_MWD+IFR2+MS+Sag(4) 13,716.01 90.75 125.04 3,744.71 3,685.59 -9,233.10 6,752.44 6,018,564.02 540,397.29 1.86 10,832.31 2 MWD+IFR2+MS+Sag(4) 13,811.70 89.08 126.00 3,744.85 3,685.73 -9,288.69 6,830.32 6,018,508.79 540,475.42 2.01 10,927.99 2_MWD+IFR2+MS+Sag (4) 13,906.97 88.41 126.72 3,746.94 3,687.82 -9,345.16 6,907.03 6,018,452.68 540,552.36 1.03 11,023.21 2_MWD+IFR2+MS+Sag(4) 14,002.18 85.93 126.76 3,751.64 3,692.52 -9,402.04 6,983.22 6,018,396.15 540,628.81 2.61 11,118.26 2_MWD+IFR2+MS+Sag (4) 14,097.07 85.37 126.08 3,758.84 3,699.72 -9,458.21 7,059.36 6,018,340.32 540,705.19 0.93 11,212.85 2_MWD+IFR2+MS+Sag(4) 14,192.09 87.73 126.76 3,764.55 3,705.43 -9,514.52 7,135.68 6,018,284.37 540,781.76 2.58 11,307.66 2_MWD+IFR2+MS+Sag(4) 14,287.06 88.47 126.21 3,767.70 3,708.58 -9,570.96 7,211.99 6,018,228.28 540,858.32 0.97 11,402.55 2_MWD+IFR2+MS+Sag(4) 14,382.77 87.85 124.72 3,770.78 3,711.66 -9,626.46 7,289.90 6,018,173.14 540,936.47 1.69 11,498.21 2_MWD+IFR2+MS+Sag(4) 14,477.50 87.85 124.36 3,774.33 3,715.21 -9,680.13 7,367.88 6,018,119.82 541,014.68 0.38 11,592.87 2_MWD+IFR2+MS+Sag(4) 14,571.82 86.74 123.83 3,778.78 3,719.66 -9,732.94 7,445.90 6,018,067.37 541,092.93 1.30 11,687.06 2_MWD+IFR2+MS+Sag(4) 14,667.77 85.99 124.07 3,784.86 3,725.74 -9,786.42 7,525.33 6,018,014.26 541,172.59 0.82 11,782.80 2_MWD+IFR2+MS+Sag(4) 14,763.13 86.55 124.49 3,791.07 3,731.95 -9,840.02 7,603.96 6,017,961.02 541,251.45 0.73 11,877.95 2_MWD+IFR2+MS+Sag (4) 14,858.16 88.16 125.47 3,795.45 3,736.33 -9,894.43 7,681.73 6,017,906.96 541,329.47 1.98 11,972.87 2_MWD+IFR2+MS+Sag (4) 14,953.86 86.98 124.32 3,799.51 3,740.39 -9,949.13 7,760.15 6,017,852.62 541,408.13 1.72 12,068.49 2_MWD+IFR2+MS+Sag(4) 15,048.86 87.42 125.18 3,804.15 3,745.03 -10,003.22 7,838.11 6,017,798.90 541,486.33 1.02 12,163.37 2_MWD+IFR2+MS+Sag(4) 15,144.15 89.28 126.44 3,806.89 3,747.77 -10,058.94 7,915.35 6,017,743.52 541,563.81 2.36 12,258.61 2_MWD+IFR2+MS+Sag(4) 15,239.52 89.95 126.80 3,807.54 3,748.42 -10,115.83 7,991.90 6,017,686.99 541,640.60 0.80 12,353.94 2_MWD+IFR2+MS+Sag(4) 15,334.18 89.89 126.25 3,807.67 3,748.55 -10,172.17 8,067.96 6,017,631.00 541,716.91 0.58 12,448.57 2_MWD+IFR2+MS+Sag(4) 15,429.34 89.33 125.69 3,808.32 3,749.20 -10,228.06 8,144.98 6,017,575.46 541,794.17 0.83 12,543.71 2_MWD+IFR2+MS+Sag(4) 15,524.22 88.65 125.93 3,809.99 3,750.87 -10,283.57 8,221.91 6,017,520.31 541,871.34 0.76 12,638.57 2_MWD+IFR2+MS+Sag(4) 15,619.16 88.53 126.14 3,812.32 3,753.20 -10,339.40 8,298.66 6,017,464.83 541,948.34 0.25 12,733.47 2_MWD+IFR2+MS+Sag (4) 15,714.67 88.84 125.67 3,814.52 3,755.40 -10,395.40 8,376.00 6,017,409.19 542,025.92 0.59 12,828.94 2_MWD+IFR2+MS+Sag(4) 15,809.96 93.17 125.77 3,812.85 3,753.73 -10,451.01 8,453.34 6,017,353.93 542,103.50 4.55 12,924.19 2 MWD+IFR2+MS+Sag(4) 15,904.91 92.30 125.40 3,808.31 3,749.19 -10,506.20 8,530.46 6,017,299.10 542,180.87 1.00 13,019.03 2_MWD+IFR2+MS+Sag(4) 16,000.06 92.48 125.26 3,804.35 3,745.23 -10,561.17 8,608.02 6,017,244.48 542,258.67 0.24 13,114.09 2_MWD+IFR2+MS+Sag(4) 6/72019 1:00:01 PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K18 Project: Milne Point TVD Reference: MPU M-18 Actual RKB @ 59.12usft Site: M Pt Moose Pad MD Reference: MPU M-18 Actual RKB @ 59.12usft Well: MPU M-18 North Reference: True Wellbore: MPU M-18 Survey Calculation Method: Minimum Curvature Design: MPU M-18 Database: NORTH US+CANADA Survey %wM4yMEVPe+n v.*gn, Checked By: Chelsea Wright `= '�" w m- Approved By: Mitch Laird "- Date: 06-07-2019 6172019 1:00:01 PM Page 7 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1180•) (ft) Survey Tool Name 16,09543 90.50 124.39 3,801.87 3,742.75 -10,615.61 8,686.28 6,017,190.40 542,337.17 2.27 13,209.42 2_MWD+IFR2+MS+Sag(4) 16,190.43 88.65 124.40 3,802.57 3,743.45 -10,669.27 8,764.67 6,017,137.10 542,415.79 1.95 13,304.41 2_MWD+IFR2+MS+Sag(4) 16,285.86 88.41 124.08 3,805.02 3,745.90 -10,722.95 8,843.53 6,017,083.78 542,494.88 0.42 13,399.80 2_MWD+IFR2+MS+Sag(4) 16,380.91 88.47 123.76 3,807.61 3,748.49 -10,775.97 8,922.38 6,017,031.12 542,573.96 0.34 13,494.79 2_MWD+IFR2+MS+Sag(4) 16,476.24 90.45 124.41 3,808.51 3,749.39 -10,829.39 9,001.32 6,016,978.06 542,653.14 2.19 13,590.10 2_MWD+IFR2+MS+Sag (4) 16,571.99 92.86 125.99 3,805.74 3,746.62 -10,884.56 9,079.52 6,016,923.26 542,731.58 3.01 13,685.80 2_MWD+IFR2+MS+Sag (4) 16,661.06 91.86 126.99 3,802.07 3,742.95 -10,937.48 9,151.07 6,016,870.67 542,803.36 1.59 13,774.76 2_MWD+IFR2+MS+Sag (4) 16,731.00 91.86 126.99 3,799.80 3,740.68 -10,979.54 9,206.90 6,016,828.86 542,859.38 0.00 13,844.63 PROJECTED to TD %wM4yMEVPe+n v.*gn, Checked By: Chelsea Wright `= '�" w m- Approved By: Mitch Laird "- Date: 06-07-2019 6172019 1:00:01 PM Page 7 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-18PB1 E•Y�IIY�:Y_�cZ:kY�L�] Sperry Drilling Definitive Survey Report 07 June, 2019 HALLIBURTON Sperry Drilling CompanIg Hiloorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-18 Wellbore: MPU M-18PB1 Design: MPU M-18PB1 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-18 MPU M-18 Actual RKB @ 59.12usft MPU M-18 Actual RKB @ 59.12usft True Minimum Curvature NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-18 ACTUAL Depth From (TVD) +NIS (usft) Well Position +NI -S 0.00 usft Northing: 6,027,765.61 usfl Latitude: +E/ -W 0.00 usft Easting: 533,603.87 usfl Longitude: Position Uncertainty 0.00 usfl Wellhead Elevation: usfl Ground Level: Wellbore MPU M-18PB1 Magnetics Model Name Sample Date Declination Dip Angle (') (1) BGGM2018 5/21/2019 16.63 80.96 Design Audit Notes: Version: Vertical Section: MPU M-18PB1 1.0 Phase: ACTUAL Depth From (TVD) +NIS (usft) (usft) 34.42 0.00 Tie On Depth: 34.42 +E/ -W Direction (usft) (I 0.00 125.08 70° 29'12.7926 N 149'43'31,2401 W 24.70 usft Field Strength (nT) 57,425.73568634 Survey Program Date 6/4/2019 From To (usft) lush) Survey (Wellbore) Tool Name Description Survey Date 164.12 8,107.51 MPU M-18PB1 MWD+IFR2+MS+Sag(1)2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/17/2019 8,200.93 10,290.73 MPU M-18PB1 MWD+IFR2+MS+sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis+ sa 06/03/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 34.42 0.00 0.00 34.42 -24.70 0.00 0.00 6,027,765.61 533,603.87 0.00 0.00 UNDEFINED 164.12 0.63 233.04 164.12 105.00 -0.43 -0.57 6,027,765.18 533,603.30 0.49 -0.22 2_MWD+IFR2+MS+Sag(1) 228.13 0.77 236.57 228.12 169.00 -0.88 -1.21 6,027,764.73 533,602.66 0.23 -0.49 2_MWD+IFR2+MS+Sag(1) 320.86 1.15 233.69 320.84 261.72 -1.77 -2.48 6,027,763.83 533,601.40 0.41 -1.01 2_MWD+IFR2+MS+Sag(1) 413.63 0.42 285.16 413.60 354.48 -2.23 -3.56 6,027,763.36 533,600.32 1.02 -1.63 2_MWD+IFR2+MS+Sag(1) 508.35 1.19 173.57 508.31 449.19 3.12 -3.78 6,027,762.47 533,600.10 1.48 -1.30 2_MWD+IFR2+MS+Sag(1) 600.39 5.14 161.73 600.20 541.08 -7.99 -2.38 6,027,757.61 533,601.52 4.33 2.64 2_MWD+IFR2+MS+Sag(1) 693.23 8.83 157.89 692.33 633.21 -18.54 1.60 6,027,747.08 533,605.56 4.00 11.97 2_MWD+IFR2+MS+Sag(1) 788.27 13.36 158.00 785.57 726.45 -35.49 8.47 6,027,730.16 533,612.50 4.77 27.33 2_MWD+IFR2+MS+Sag(1) 881.76 17.72 160.63 875.62 816.50 -58.94 17.24 6,027,706.76 533,621.37 4.72 47.98 2_MWD+IFR2+MS+Sag(1) 978.32 21.30 162.90 966.63 907.51 -89.57 27.27 6,027,676.17 533,631.54 3.79 73.80 2_MWD+IFR2+MS+Sag(1) 1,073.27 24.70 163.70 1,054.01 994.89 -125.11 37.91 6,027,640.69 533,642.34 3.60 102.93 2_MWD+IFR2+MS+Sag (1) 1,166.03 28.70 165.29 1,136.87 1,077.75 -165.27 49.01 6,027,600.58 533,653.62 4.38 135.09 2_MWD+IFR2+MS+Sag(1) 61712019 12.57.27PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU LI -18 Project: Milne Point TVD Reference: MPU M-18 Actual RKB @ 59.12usft Site: M Pt Moose Pad MD Reference: MPU M-18 Actual RKB @ 59.12usft Well: MPU M-18 North Reference: True Wellbore: MPU M -18P61 Survey Calculation Method: Minimum Curvature Design: MPU M-18PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) V) 0 (usft) (usft) (usft) (usft) (ft) (ft) ('I100') (ft) Survey Tool Name 1,261.82 33.09 166.06 1,219.05 1,159.93 -212.92 61.16 6,027,552.99 533,665.98 4.60 172.42 2_MWD+IFR2+MS+Sag(1) 1,355.20 35.74 167.74 1,296.08 1,236.96 -264.32 73.09 6,027,501.65 533,678.15 3.01 211.72 2_MWD+IFR2+MS+Sag(1) 1,453.28 38.48 168.57 1,374.29 1,315.17 -322.23 85.22 6,027,443.80 533,690.54 2.84 254.94 2_MWD+IFR2+MS+Sag(1) 1,548.91 41.19 166.89 1,447.72 1,388.60 -382.07 98.27 6,027,384.02 533,703.85 3.05 300.00 2_MWD+IFR2+MS+Sag(1) 1,643.82 44.35 165.00 1,517.38 1,458.26 -444.57 113.94 6,027,321.60 533,719.81 3.59 348.75 2_MWD+IFR2+MS+Sag(1) 1,736.64 49.58 163.45 1,580.71 1,521.59 -509.83 132.42 6,027,256.44 533,738.58 5.76 401.37 2_MWD+IFR2+MS+Sag(1) 1,832.69 52.77 163.31 1,640.92 1,581.80 5 81.52 153.82 6,027,184.85 533,760.30 3.32 460.09 2_MWD+IFR2+MS+Sag(1) 1,927.74 57.39 162.96 1,695.31 1,636.19 -656.08 176.43 6,027,110.40 533,783.25 4.87 521.45 2_MWD+IFR2+MS+Sag(1) 2,023.82 63.05 161.79 1,743.01 1,683.89 -735.52 201.69 6,027,031.09 533,808.86 5.98 587.77 2_MWD+IFR2+MS+Sag(1) 2,118.64 66.96 162.85 1,783.07 1,723.95 -817.38 227.78 6,026,949.34 533,835.31 4.25 656.17 2_MWD+IFR2+MS+Sag(1) 2,213.65 68.76 163.66 1,818.88 1,759.76 -901.65 253.13 6,026,865.20 533,861.04 2.05 725.34 2_MWD+IFR2+MS+Sag(1) 2,309.25 69.69 165.45 1,852.79 1,793.67 -987.80 276.92 6,026,779.16 533,885.23 2.00 794.33 2_MWD+IFR2+MS+Sag(1) 2,404.74 69.49 165.05 1,886.09 1,826.97 -1,074.35 299.71 6,026,692.73 533,908.40 0.44 862.72 2_MWD+IFR2+MS+Sag(1) 2,499.30 69.70 164.97 1,919.06 1,859.94 -1,159.96 322.63 6,026,607.23 533,931.71 0.24 930.68 2_MWD+IFR2+MS+Sag(1) 2,593.72 69.17 165.63 1,952.22 1,893.10 -1,245.47 345.07 6,026,521.84 533,954.53 0.86 998.18 2_MWD+IFR2+MS+Sag(1) 2,689.41 70.41 165.74 1,985.28 1,926.16 -1,332.48 367.27 6,026,434.94 533,977.12 1.30 1,066.36 2_MWD+IFR2+MS+Sag(1) 2,784.18 69.43 165.54 2,017.82 1,958.70 -1,418.71 389.34 6,026,348.82 533,999.58 1.05 1,133.98 2_MWD+IFR2+MS+Sag(1) 2,879.83 69.78 164.03 2,051.15 1,992.03 -1,505.21 412.87 6,026,262.43 534,023.50 1.52 1,202.95 2_MWD+IFR2+MS+Sag(1) 2,974.20 69.29 164.26 2,084.15 2,025.03 -1,590.26 437.03 6,026,177.49 534,048.04 0.57 1,271.60 2_MWD+IFR2+MS+Sag(1) 3,069.19 69.55 162.91 2,117.54 2,058.42 -1,675.56 462.16 6,026,092.32 534,073.55 1.36 1,341.19 2_MWD+IFR2+MS+Sag(1) 3,164.07 69.62 163.70 2,150.64 2,091.52 -1,760.74 487.70 6,026,007.27 534,099.48 0.78 1,411.04 2_MWD+IFR2+MS+Sag(1) 3,258.32 68.99 164.33 2,183.94 2,124.82 -1,845.49 511.98 6,025,922.63 534,124.14 0.92 1,479.62 2_MWD+IFR2+MS+Sag(1) 3,353.64 67.46 164.78 2,219.30 2,160.18 -1,930.81 535.56 6,025,837.43 534,148.09 1.66 1,547.95 2_MWD+IFR2+MS+Sag(1) 3,449.51 68.77 164.36 2,255.04 2,195.92 -2,016.56 559.23 6,025,751.79 534,172.15 1.43 1,616.60 2_MWD+IFR2+MS+Sag(1) 3,544.38 69.89 164.31 2,288.52 2,229.40 -2,102.03 583.20 6,025,666.44 534,196.50 1.18 1,685.34 2_MWD+IFR2+MS+Sag(1) 3,639.31 69.75 165.47 2,321.27 2,262.15 -2,188.05 606.42 6,025,580.54 534,220.11 1.16 1,753.78 2_MWD+IFR2+MS+Sag(1) 3,735.11 70.62 165.81 2,353.75 2,294.63 -2,275.36 628.77 6,025,493.34 534,242.86 0.97 1,822.25 2_MWD+IFR2+MS+Sag(1) 3,829.24 70.74 164.38 2,384.89 2,325.77 -2,361.20 651.62 6,025,407.61 534,266.09 1.44 1,890.28 2_MWD+IFR2+MS+Sag(1) 3,924.40 68.90 163.55 2,417.72 2,358.60 -2,447.04 676.29 6,025,321.89 534,291.14 2.10 1,959.80 2_MWD+IFR2+MS+Sag(1) 4,018.80 67.86 163.50 2,452.50 2,393.38 -2,531.19 701.18 6,025,237.86 534,316.41 1.10 2,028.53 2_MWD+IFR2+MS+Sag(1) 4,113.73 69.30 163.84 2,487.17 2,428.05 -2,616.00 726.02 6,025,153.18 534,341.63 1.55 2,097.61 2_MWD+IFR2+MS+Sag(1) 4,209.64 70.79 164.13 2,519.90 2,460.78 -2,702.65 750.89 6,025,066.65 534,366.89 1.58 2,167.76 2_MWD+IFR2+MS+Sag(1) 4,305.45 71.60 163.15 2,550.78 2,491.66 -2,789.67 776.44 6,024,979.75 534,392.83 1.29 2,238.68 2_MWD+IFR2+MS+Sag(1) 4,400.02 69.23 162.44 2,582.48 2,523.36 -2,874.78 802.79 6,024,894.77 534,419.56 2.60 2,309.15 2_MWD+IFR2+MS+Sag(1) 4,495.37 70.67 161.82 2,615.17 2,556.05 -2,960.02 830.28 6,024,809.66 534,447.43 1.63 2,380.64 2_MWD+IFR2+MS+Sag(1)M 4,590.52 68.95 162.19 2,648.01 2,588.89 -3,044.95 857.87 6,024,724.86 534,475.40 1.84 2,45PA3 2_WD+IFR2+MS+Sag(1) 4,686.01 66.82 162.61 2,683.96 2,624.84 -3,129.27 884.62 6,024,640.68 534,502.53 2.27 2,522.38 2_MWD+IFR2+MS+Sag(1) 4,781.07 66.62 163.43 2,721.53 2,662.41 -3,212.78 910.12 6,024,557.29 534,528.40 0.82 2,591.24 2_MWD+IFR2+MS+Sag(1) 4,876.39 69.02 164.38 2,757.51 2,698.39 -3,297.59 934.58 6,024,472.61 534,553.24 2.68 2,660.00 2_MWD+IFR2+MS+Sag(1) 4,971.39 69.09 164.36 2,791.47 2,732.35 -3,383.03 958.48 6,024,387.28 534,577.53 0.08 2,728.67 2_MWD+IFR2+MS+Sag(1) 67!2019 12:57 27PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-18 Project: Milne Point TVD Reference: MPU M-18 Actual RKB @ 59.12usft Site: M Pt Moose Pad MD Reference: MPU M-18 Actual RKB @ 59.12usft Well: MPU M-18 North Reference: True Wellbore: MPU M-18PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-18PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (^1180•) (ft) Survey Tool Name 5,066.98 70.35 165.28 2,824.60 2,765.48 -3,469.56 981.96 6,024,300.86 534,601.40 1.60 2,797.61 2_MWD+IFR2+MS+Sag(1) 5,162.02 70.29 165.04 2,856.61 2,797.49 -3,556.06 1,004.88 6,024,214.47 534,624.70 0.25 2,866.08 2_MWD+IFR2+MS+Sag(1) 5,256.79 69.24 165.80 2,889.39 2,830.27 -3,642.12 1,027.26 6,024,128.53 534,647.48 1.34 2,933.86 2_MWD+IFR2+MS+Sag(1) 5,351.88 71.47 165.95 2,921.35 2,862.23 3,728.96 1,049.12 6,024,041.79 534,669.72 2.35 3,001.65 2_MWD+IFR2+MS+Sag(1) 5,447.58 72.10 166.58 2,951.27 2,892.15 -3,817.27 1,070.70 6,023,953.60 534,691.70 0.91 3,070.06 2_MWD+IFR2+MS+Sag(1) 5,542.87 71.93 167.36 2,980.69 2,921.57 -3,905.57 1,091.13 6,023,865.40 534,712.53 0.80 3,137.53 2_MWD+IFR2+MS+Sag(1) 5,638.19 72.58 165.32 3,009.74 2,950.62 -3,993.78 1,112.57 6,023,777.30 534,734.37 2.15 3,205.78 2_MWD+IFR2+MS+Sag(1) 5,732.84 71.14 165.06 3,039.21 2,980.09 3,080.73 1,135.56 6,023,690.45 534,757.75 1.54 3,274.57 2_MWD+IFR2+MS+Sag(1) 5,829.48 68.77 164.71 3,072.33 3,013.21 3,168.37 1,159.23 6,023,602.93 534,781.81 2.48 3,344.30 2 MWD+IFR2+MS+Sag(1) 5,924.62 69.58 164.99 3,106.16 3,047.04 4,254.20 1,182.47 6,023,517.21 534,805.43 0.89 3,412.65 2_MWD+IFR2+MS+Sag(1) 6,019.97 67.76 165.20 3,140.84 3,081.72 3 1,205.32 6,023,431.50 534,828.67 1.92 M,340.03 3,480.67 2_WD+IFR2+MS+Sag(1) 6,114.44 67.10 163.47 3,177.10 3,117.98 3,424.02 1,228.87 6,023,347.62 534,852.59 1.83 3,548.22 2_MWD+IFR2+MS+Sag(1) 6,208.68 68.43 163.60 3,212.76 3,153.64 3,507.67 1,253.59 6,023,264.09 534,877.69 1.42 3,616.53 2_MWD+IFR2+MS+Sag(1) 6,304.35 67.43 163.10 3,248.71 3,189.59 3,592.62 1,278.99 6,023,179.27 534,903 1.15 M47 3,686.13 2_WD+IFR2+MS+Sag(1) 6,399.44 67.44 162.96 3,285.20 3,226.08 3,676.60 1,304.62 6,023,095.41 534,929.48 0.14 3,755.37 2_MWD+IFR2+MS+Sag(1) 6,494.73 69.37 162.72 3,320.26 3,261.14 3,761.26 1,330.76 6,023,010.89 534,956.00 2.04 3,825.42 2_MWD+IFR2+MS+Sag(1) 6,589.48 68.17 162.74 3,354.57 3,295.45 3,845.59 1,356.98 6,022,926.68 534,982.60 1.27 3,895.34 2_MWD+IFR2+MS+Sag(1) 6,684.72 66.44 163.64 3,391.32 3,332.20 3,929.70 1,382.40 6,022442.70 535,008.39 2.01 3,964.48 2_MWD+IFR2+MS+Sag(1) 6,779.98 68.42 164.82 3,427.88 3,368.76 -5,014.35 1,406.30 6,022,758.16 535,032.67 2.37 4,032.69 2_MWD+IFR2+MS+Sag(1) 6,874.67 72.82 162.88 3,459.30 3,400.18 -5,100.11 1,431.15 6,022,672.52 535,057.91 5.03 4,102.32 2_MWD+IFR2+MS+Sag(1) 6,970.24 73.85 159.70 3,486.71 3,427.59 -5,186.82 1,460.52 6,022,585.96 535,087.67 3.36 4,176.18 2_MWD+IFR2+MS+Sag(1) 7,065.15 73.01 157.01 3,513.78 3,454.66 -5,271.36 1,494.07 6,022,501.57 535,121.59 2.86 4,252.23 2_MWD+IFR2+MS+Sag(1) 7,161.17 74.56 153.32 3,540.60 3,481.48 -5,355.01 1,532.80 6,022,418.11 535,160.69 4.03 4,331.99 2_MWD+IFR2+MS+Sag(1) 7,255.19 75.27 150.87 3,565.07 3,505.95 -5,435.23 1,575.28 6,022,338.09 535,203.54 2.63 4,412.86 2_MWD+IFR2+MS+Sag(1) 7,351.21 77.54 146.59 3,587.65 3,528.53 -5,514.96 1,623.72 6,022,258.58 535,252.33 4.94 4,498.33 2_MWD+IFR2+MS+Sag (1) 7,443.28 78.60 141.58 3,606.70 3,547.58 -5,587.89 1,676.55 6,022,185.90 535,305.48 5.45 4,583.48 2_MWD+IFR2+MS+Sag(1) 7,540.79 79.51 137.89 3,625.22 3,566.10 -5,660.92 1,738.42 6,022,113.16 535,367.68 3.83 4,676.08 2_MWD+IFR2+MS+Sag(1) 7,636.36 79.25 132.84 3,642.84 3,583.72 -5,727.74 1,804.39 6,022,046.64 535,433.94 5.20 4,768.47 2_MWD+IFR2+MS+Sag(1) 7,732.26 77.61 127.72 3,662.09 3,602.97 -5,788.47 1,876.03 6,021,986.24 535,505.85 5.50 4,862.00 2_MWD+IFR2+MS+Sag(1) 7,827.17 75.51 125.72 3,684.15 3,625.03 -5,843.66 1,950.01 6,021,931.39 535,580.07 3.02 4,954.26 2 MWD+IFR2+MS+Sag(1)M 7,922.47 78.13 124.22 3,705.88 3,646.76 -5,896.84 2,026.04 6,021,878.57 535,656.33 3.15 5,047.04 2_WD+IFR2+MS+Sag(1) 8,017.15 82.89 123.49 3,721.48 3,662.36 -5,948.84 2,103.57 6,021,826.92 535,734.09 5.08 5,140.38 2_MWD+IFR2+MS+Sag(1) 8,107.51 90.68 124.69 3,726.55 3,667.43 -5,999.37 2,178.23 6,021,776.73 535,808.96 8.72 5,230.51 2_MWD+IFR2+MS+Sag(1) 8,200.93 91.06 125.48 3,725.13 3,666.01 -6,053.06 2,254.66 6,021,723.40 535,885.63 0.94 5,323.92 2_MWD+IFR2+MS+Sag (2) 8,296.65 88.15 124.03 3,725.79 3,666.67 -6,107.62 2,333.29 6,021,669.20 535,964.50 3.40 5,419.62 2_MWD+IFR2+MS+Sag (2) 8,391.43 86.68 124.51 3,730.06 3,670.94 -6,160.93 2,411.54 6,021,616.24 536,042.98 1.63 5,514.29 2_MWD+IFR2+MS+Sag(2) 8,482.98 86.68 123.75 3,735.36 3,676.24 -6,212.21 2,487.19 6,021,565.31 536,118.86 0.83 5,605.67 2_MWD+IFR2+MS+Sag(2) 8,578.98 87.73 125.25 3,740.05 3,680.93 -6,266.52 2,566.21 6,021,511.37 536,198.11 1.91 5,701.55 2_MWD+IFR2+MS+Sag (2) 8,676.33 91.38 129.73 3,740.80 3,681.68 -6,325.74 2,643.42 6,021,452.50 536,275.58 5.94 5,798.77 2_MWD+IFR2+MS+Sag(2) 8,770.75 90.07 129.85 3,739.61 3,680.49 -6,386.16 2,715.96 6,021,392.41 536,348.39 1.39 5,892.86 2_MWD+IFR2+MS+Sag(2) 6/7/2019 12.:57:27PM Page 4 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-18 Wellbore: MPU M-18PB1 Design: MPU M-18PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU Mt -18 MPU M-18 Actual RKB @ 59.12usfl MPU M-18 Actual RKB @ 59.12usfl True Minimum Curvature NORTH US + CANADA Checked By: Chelsea Wright°°[ m gpproved By: Mitch Laird -•M Date: 06-07-2019 6/7/2019 12.57:27PM Page 5 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100•) (ft) Survey Tool Name 8,867.27 91.19 127.78 3,738.55 3,679.43 -6,446.66 2,791.16 6,021,332.27 536,423.85 2.44 5,989.16 2_MWD+IFR2+MS+Sag(2) 8,962.03 88.66 125.07 3,738.67 3,679.55 -6,502.91 2,867.39 6,021,276.36 536,500.33 3.91 6,083.88 2_MWD+IFR2+MS+Sag (2) 9,056.53 87.91 123.29 3,741.50 3,682.38 -6,555.98 2,945.53 6,021,223.66 536,578.70 2.04 6,178.32 2_MWD+IFR2+MS+Sag 12)M 9,151.62 86.49 122.31 3,746.14 3,687.02 -6,607.42 3,025.36 6,021,172.57 536,658.75 1.81 6,273.22 2_WD+IFR2+MS+Sag(2) 9,246.25 88.16 123.51 3,750.56 3,691.44 -6,658.78 3,104.71 6,021,121.58 536,738.33 2.17 6,367.68 2_MWD+IFR2+MS+Sag (2) 9,341.19 90.01 126.19 3,752.08 3,692.96 -6,713.02 3,182.61 6,021,067.70 536,816.46 3.43 6,462.59 2_MWD+IFR2+MS+Sag (2) 9,436.04 90.26 126.51 3,751.85 3,692.73 -6,769.24 3,259.00 6,021,011.84 536,893.10 0.43 6,557.42 2_MWD+IFR2+MS+Sag(2) 9,529.82 88.90 126.43 3,752.54 3,693.42 -6,824.98 3,334.41 6,020,956.44 536,968.75 1.45 6,651.16 2_MWD+IFR2+MS+Sag (2) 9,626.24 87.91 125.85 3,755.22 3,696.10 -6,881.82 3,412.25 6,020,899.96 537,046.84 1.19 6,747.53 2_MWD+IFR2+MS+Sag(2) 9,721.05 88.16 124.23 3,758.47 3,699.35 -6,936.22 3,489.82 6,020,845.91 537,124.65 1.73 6,842.28 2_MWD+IFR2+MS+Sag(2) 9,816.23 88.16 125.21 3,761.53 3,702.41 -6,990.40 3,568.01 6,020,792.09 537,203.08 1.03 6,937.41 2_MWD+IFR2+MS+Sag (2) 9,910.38 89.34 123.72 3,763.58 3,704.46 -7,043.67 3,645.62 6,020,739.18 537,280.91 2.02 7,031.53 2_MWD+IFR2+MS+Sag(2) 10,005.54 93.17 123.18 3,761.50 3,702.38 -7,096.10 3,724.98 6,020,687.12 537,360.50 4.06 7,126.61 2_MWD+IFR2+MS+Sag (2) 10,100.80 93.10 123.17 3,756.29 3,697.17 -7,148.15 3,804.59 6,020,635.43 537,440.34 0.07 7,221.67 2_MWD+IFR2+MS+Sag(2) 10,196.49 92.11 123.49 3,751.94 3,692.82 -7,200.67 3,884.46 6,020,583.28 537,520.44 1.09 7,317.22 2_MWD+IFR2+MS+Sag(2) 10,290.73 93.60 124.37 3,747.25 3,688.13 -7,253.20 3,962.55 6,020,531.10 537,598.76 1.84 7,411.32 2_MWD+IFR2+MS+Sag (2) 10,361.00 93.60 124.37 3,742.84 3,683.72 -7,292.79 4,020.44 6,020,491.77 537,656.82 0.00 7,481.44 PROJECTED to TD Checked By: Chelsea Wright°°[ m gpproved By: Mitch Laird -•M Date: 06-07-2019 6/7/2019 12.57:27PM Page 5 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-18PB2 500292363271 Sperry Drilling Definitive Survey Report 07 June, 2019 HALLIBURTON Sperry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-18 Wellbore: MPU M-18PB2 Design: MPU M-18PB2 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU M-18 MPU M-18 Actual RKB @ 59.12usft MPU M-18 Actual IRKS @ 59.12usft True Minimum Curvature NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-18 Well Position +N/ -S +EI -W Position Uncertainty Wellbore MPU M-18PB2 Magnetics Model Name 0.00 usft Northing: 6,027,765.61 usfl 0.00 usft Easting: 533,603.87 usfl 0.00 usft Wellhead Elevation: usfl Sample Date Declination (') BGGM2018 6/3/2019 16.61 Design MPU M-18PB2 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +N/ -S (usft) (usft) 34.42 0.00 Latitude: Longitude: Ground Level: Dip Angle C) 80.96 70° 29' 12.7926 N 149° 43'31.2401 W 24.70 usft Field Strength (nT) 57,424.40213548 Tie On Depth: 9,910.38 +EI -W Direction (usft) (') 0.00 125.08 Survey Program Date 6/4/2019 From To (usfl) (usft) Survey (Wellbore) Tool Name Description Survey Date 164.12 8,107.51 MPU M-18PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/17/2019 8,200.93 9,910.38 MPU M-18PB1 MWD+IFR2+MS+sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 06/03/2019 9,990.00 11,696.69 MPU M-18PB2 MWD+IFR2+MS+sag (3) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 06/03/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (o170o') (ft) Survey Tool Name 34.42 0.00 0.00 34.42 -24.70 0.00 0.00 6,027,765.61 533,603.87 0.00 0.00 UNDEFINED 164.12 0.63 233.04 164.12 105.00 -0.43 -0.57 6,027,765.18 533,603.30 0.49 -0.22 2_MWD+IFR2+MS+Sag(1) 228.13 0.77 236.57 228.12 169.00 -0.88 -1.21 6,027,764.73 533,602.66 0.23 -0.49 2_MWD+IFR2+MS+Sag(1) 320.86 1.15 233.69 320.84 261.72 -1.77 -2.48 6,027,763.83 533,601.40 0.41 -1.01 2_MWD+IFR2+MS+Sag(1) 413.63 0.42 285.16 413.60 354.48 -2.23 -3.56 6,027,763.36 533,600.32 1.02 -1.63 2_MWD+IFR2+MS+Sag(1) 508.35 1.19 173.57 508.31 449.19 -3.12 -3.78 6,027,762.47 533,600.10 1.48 -1.30 2_MWD+IFR2+MS+Sag(1) 600.39 5.14 161.73 600.20 541.08 -7.99 -2.38 6,027,757.61 533,601.52 4.33 2.64 2_MWD+IFR2+MS+Sag(1) 693.23 8.83 157.89 692.33 633.21 -18.54 1.60 6,027,747.08 533,605.56 4.00 11.97 2_MWD+IFR2+MS+Sag(1) 788.27 13.36 158.00 785.57 726.45 -35.49 8.47 6,027,730.16 533,612.50 4.77 27.33 2_MWD+IFR2+MS+Sag(1) 881.76 17.72 160.63 875.62 816.50 -58.94 17.24 6,027,706.76 533,621.37 4.72 47.98 2_MWD+IFR2+MS+Sag(1) 978.32 21.30 162.90 966.63 907.51 -89.57 27.27 6,027,676.17 533,631.54 3.79 73.80 2_MWD+IFR2+MS+Sag(1)M 1,073.27 24.70 163.70 1,054.01 994.89 -125.11 37.91 6,027,640.69 533,642.34 3.60 102.93 2_WD+IFR2+MS+Sag(1) 677/2019 12:58:57PM Page 2 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-18 Wellbore: MPU M-18PB2 Design: MPU M-18PB2 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU Mt -18 MPU M-18 Actual RKB @ 59.12usft MPU M-18 Actual RKB @ 59.12usft True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +El -W Northing Easting DLS Section (usft) (1) r) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,166.03 28.70 165.29 1,136.87 1,077.75 -165.27 49.01 6,027,600.58 533,653.62 4.38 135.09 2_MWD+IFR2+MS+Sag(1) 1,261.82 33.09 166.06 1,219.05 1,159.93 -212.92 61.16 6,027,552.99 533,665.98 4.60 172.42 2_MWD+IFR2+MS+Sag(1) 1,355.20 35.74 167.74 1,296.08 1,236.96 -264.32 73.09 6,027,501.65 533,678.15 3.01 211.72 2_MWD+IFR2+MS+Sag(1) 1,453.28 38.48 168.57 1,374.29 1,315.17 -322.23 85.22 6,027,443.80 533,690.54 2.84 254.94 2_MWD+IFR2+MS+Sag(1) 1,548.91 41.19 166.89 1,447.72 1,388.60 -382.07 98.27 6,027,384.02 533,703.85 3.05 300.00 2_MWD+IFR2+MS+Sag(1) 1,643.82 44.35 165.00 1,517.38 1,458.26 -444.57 113.94 6,027,321+60 533,719.81 3.59 348.75 2_MWD+IFR2+MS+Sag(1) 1,736.64 49.58 163.45 1,580.71 1,521.59 -509.83 132.42 6,027,256.44 533,738.58 5.76 401.37 2_MWD+IFR2+MS+Sag(1) 1,832.69 52.77 163.31 1,640.92 1,581.80 -581.52 153.82 6,027,184.85 533,760.30 3.32 460.09 2_MWD+IFR2+MS+Sag(1) 1,927.74 57.39 162.96 1,695.31 1,636.19 -656.08 176.43 6,027,110.40 533,783.25 4.87 521.45 2_MWD+IFR2+MS+Sag(1) 2,023.82 63.05 161.79 1,743.01 1,683.89 -735.52 201.69 6,027,031.09 533,808.86 5.98 587.77 2_MWD+IFR2+MS+Sag(1) 2,118.64 66.96 162.85 1,783.07 1,723.95 -817.38 227.78 6,026,949.34 533,835.31 4.25 656.17 2_MWD+IFR2+MS+Sag(1) 2,213.65 68.76 163.66 1,818.88 1,759.76 -901.65 253.13 6,026,865.20 533,861.04 2.05 725.34 2_MWD+IFR2+MS+Sag(1) 2,309.25 69.69 165.45 1,852.79 1,793.67 -987.80 276.92 6,026,779.16 533,885.23 2.00 794.33 2_MWD+IFR2+MS+Sag(1) 2,404.74 69.49 165.05 1,886.09 1,826.97 -1,074.35 299.71 6,026,692.73 533,908.40 0.44 862.72 2_MWD+IFR2+MS+Sag(1) 2,499.30 69.70 164.97 1,919.06 1,859.94 -1,159.96 322.63 6,026,607.23 533,931.71 0.24 930.68 2_MWD+IFR2+MS+Sag(1) 2,593.72 69.17 165.63 1,952.22 1,893.10 -1,245.47 345.07 6,026,521.84 533,954.53 0.86 998.18 2_MWD+IFR2+MS+Sag(1) 2,689.41 70.41 165.74 1,985.28 1,926.16 -1,332.48 367.27 6,026,434.94 533,977.12 1.30 1,066.36 2_MWD+IFR2+MS+Sag(1) 2,784.18 69.43 165.54 2,017.82 1,958.70 -1,418.71 389.34 6,026,348.82 533,999.58 1.05 1,133.98 2_MWD+IFR2+MS+Sag(1) 2,879.83 69.78 164.03 2,051.15 1,992.03 -1,505.21 412.87 6,026,262.43 534,023.50 1.52 1,202.95 2_MWD+IFR2+MS+Sag(1) 2,974.20 69.29 164.26 2,084.15 2,025.03 -1,590.26 437.03 6,026,177.49 534,048.04 0.57 1,271.60 2_MWD+IFR2+MS+Sag(1) 3,069.19 69.55 162.91 2,117.54 2,058.42 -1,675.56 462.16 6,026,092.32 534,073.55 1.36 1,341.19 2_MWD+IFR2+MS+Sag(1) 3,164.07 69.62 163.70 2,150.64 2,091.52 -1,760.74 487.70 6,026,007.27 534,099.48 0.78 1,411.04 2_MWD+IFR2+MS+Sag(1) 3,258.32 68.99 164.33 2,183.94 2,124.82 -1,845.49 511.98 6,025,922.63 534,124.14 0.92 1,479.62 2_MWD+IFR2+MS+Sag(1) 3,353.64 67.46 164.78 2,219.30 2,160.18 -1,930.81 535.56 6,025,837.43 534,148.09 1.66 1,547.95 2_MWD+IFR2+MS+Sag(1)M 3,449.51 68.77 164.36 2,255.04 2,195.92 -2,016.56 559.23 6,025,751.79 534,172.15 1.43 1,616.60 2_WD+IFR2+MS+Sag(1) 3,544.38 69.89 164.31 2,288.52 2,229.40 -2,102.03 583.20 6,025,666.44 534,196.50 1.18 1,685.34 2_MWD+IFR2+MS+Sag(1) 3,639.31 69.75 165.47 2,321.27 2,262.15 -2,188.05 606.42 6,025,580.54 534,220.11 1.16 1,753.78 2_MWD+IFR2+MS+Sag(1) 3,735.11 70.62 165.81 2,353.75 2,294.63 -2,275.36 628.77 6,025,493.34 534,242.86 0.97 1,822.25 2_MWD+IFR2+MS+Sag(1) 3,829.24 70.74 164.38 2,384.89 2,325.77 -2,361.20 651.62 6,025.407.61 534,266.09 1.44 1,890.28 2_MWD+IFR2+MS+Sag(1) 3,924.40 68.90 163.55 2,417.72 2,358.60 -2,447.04 676.29 6,025,321.89 534,291.14 2.10 1,959.80 2_MWD+IFR2+MS+Sag(1) 4,018.80 67.86 163.50 2,452.50 2,393.38 -2,531.19 701.18 6,025,237.86 534,316.41 1.10 2,028.53 2_MWD+IFR2+MS+Sag(1) 4,113.73 69.30 163.84 2,487.17 2,428.05 -2,616.00 726.02 6,02 5,153.18 534,341.63 1.55 M 2,097.61 2_WD+IFR2+MS+Sag(1) 4,209.64 70.79 164.13 2,519.90 2,460.78 -2,702.65 750.89 6,025,066.65 534,366.89 1.58 2,167.76 2_MWD+IFR2+MS+Sag(1) 4,305.45 71.60 163.15 2,550.78 2,491.66 -2,789.67 776.44 6,024,979.75 534,392.83 1.29 2,238.68 2_MWD+IFR2+MS+Sag(1) 4,400.02 69.23 162.44 2,582.48 2,523.36 -2,874.78 802.79 6,024,894.77 534,419.56 2.60 2,309.15 2_MWD+IFR2+MS+Sag(1) 4,495.37 70.67 161.82 2,615.17 2,556.05 -2,960.02 830.28 6,024,809+66 534,447.43 1.63 2,380.64 2_MWD+IFR2+MS+Sag(1) 4,590.52 68.95 162.19 2,648.01 2,588.89 3,044.95 857.87 6,024,724.86 534,475.40 1.84 2,452.03 2_MWD+IFR2+MS+Sag(1) 4,686.01 66.82 162.61 2,683.96 2,624.84 -3,129.27 884.62 6.024,640.68 534,502.53 2.27 2,522.38 2_MWD+IFR2+MS+Sag(1) 4,781.07 66.62 163.43 2,721.53 2,662.41 -3,212.78 910.12 6,024,557.29 534,528.40 0.82 2,591.24 2_MWD+IFR2+MS+Sag(1) 4,876.39 69.02 164.38 2,757.51 2,698.39 -3,297.59 934.58 6,024,472.61 534,553.24 2.68 2,660.00 2_MWD+IFR2+MS+Sag(1) 8/7/2019 12:58:57PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-18 Project: Milne Point TVD Reference: MPU M-18 Actual RKB @ 59.12usft Site: M Pt Moose Pad MD Reference: MPU M-18 Actual RKB @ 59.12usft Well: MPU M-18 North Reference: True Wellbore: MPU M-18PB2 Survey Calculation Method: Minimum Curvature Design: MPU M-18PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,971.39 69.09 164.36 2,791.47 2,732.35 -3,383.03 958.48 6,024,38728 534,577.53 0.08 2,728.67 2_MWD+IFR2+MS+Sag(1) 5,066.98 70.35 165.28 2,824.60 2,765.48 -3,469.56 981.96 6,024,300.86 534,601.40 1.60 2,797.61 2_MWD+IFR2+MS+Sag(1) 5,162.02 70.29 165.04 2,856.61 2,797.49 -3,556.06 1,004.88 6,024,214.47 534,624.70 0.25 2,866.08 2_MWD+IFR2+MS+Sag(1) 5,256.79 69.24 165.80 2,889.39 2,830.27 -3,642.12 1,027.26 6,024,128.53 534,647.48 1.34 2,933.86 2_MWD+IFR2+MS+Sag(1) 5,351.88 71.47 165.95 2,921.35 2,862.23 -3,728.96 1,049.12 6,024,041.79 534,669.72 2.35 3,001.65 2_MWD+IFR2+MS+Sag(1) 5,447.58 72.10 166.58 2,951.27 2,892.15 -3,817.27 1,070.70 6,023,953.60 534,691.70 0.91 3,070.06 2_MWD+IFR2+MS+Sag(1) 5,542.87 71.93 167.36 2,980.69 2,921.57 -3,905.57 1,091.13 6,023,865.40 534,712.53 0.80 3,137.53 2_MWD+IFR2+MS+Sag(1) 5,638.19 72.58 165.32 3,009.74 2,950.62 -3,993.78 1,112.57 6,023,777.30 534,734.37 2.15 3,205.78 2_MWD+IFR2+MS+Sag (1) 5,732.84 71.14 165.06 3,039.21 2,980.09 -4,080.73 1,135.56 6,023,690.45 534,757.75 1.54 3,274.57 2 MWD+IFR2+MS+Sag(1) 5,829.48 68.77 164.71 3,072.33 3,013.21 4,168.37 1,159.23 6,023,602.93 534,781.81 2.48 3,344.30 2_MWD+IFR2+MS+Sag(1) 5,924.62 69.58 164.99 3,106.16 3,047.04 -4,254.20 1,182.47 6,023,517.21 534,805.43 0.89 3,412.65 2_MWD+IFR2+MS+Sag(1) 6,019.97 67.76 165.20 3,140.84 3,081.72 -4,340.03 1,205.32 6,023,431.50 534,828.67 1.92 3,480.67 2_MWD+IFR2+MS+Sag(1) 6,114.44 67.10 163.47 3,177.10 3,117.98 4,424.02 1,228.87 6,023,347.62 534,852.59 1.83 3,548.22 2_MWD+IFR2+MS+Sag(1) 6,208.68 68.43 163.60 3,212.76 3,153.64 4,507.67 1,253.59 6,023,264.09 534,877.69 1.42 3,616.53 2_MWD+IFR2+MS+Sag(1) 6,304.35 67.43 163.10 3,248.71 3,189.59 4,592.62 1,278.99 6,023,179.27 534,903.47 1.15 3,686.13 2_MWD+IFR2+MS+Sag(1) 6,399.44 67.44 162.96 3,285.20 3,226.08 4,676.60 1,304.62 6,023,095.41 534,929.48 0.14 3,755.37 2_MWD+IFR2+MS+Sag(1) 6,494.73 69.37 162.72 3,320.26 3,261.14 4,761.26 1,330.76 6,023,010.89 534,956.00 2.04 3,825.42 2_MWD+IFR2+MS+Sag(1) 6,589.48 68.17 162.74 3,354.57 3,295.45 4,845.59 1,356.98 6,022,926.68 534,982.60 1.27 3,895.34 2_MWD+IFR2+MS+Sag(1) 6,684.72 66.44 163.64 3,391.32 3,332.20 4,929.70 1,382.40 6,022,842.70 535,008.39 2.01 3,964.48 2_MWD+IFR2+MS+Sag(1) 6,779.98 68.42 164.82 3,427.88 3,368.76 -5,014.35 1,406.30 6,022,758.16 535,032.67 2.37 4,032.69 2_MWD+IFR2+MS+Sag (1) 6,874.67 72.82 162.88 3,459.30 3,400.18 -5,100.11 1,431.15 6,022,672.52 535,057.91 5.03 4,102.32 2_MWD+IFR2+MS+Sag(1) 6,970.24 73.85 159.70 3,486.71 3,427.59 -5,186.82 1,460.52 6,022,585.96 535,087.67 3.36 4,176.18 2_MWD+IFR2+MS+Sag(1) 7,065.15 73.01 157.01 3,513.78 3,454.66 -5,271.36 1,494.07 6,022,501.57 535,121.59 2.86 4,252.23 2_MWD+IFR2+MS+Sag(1) 7,161.17 74.56 153.32 3,540.60 3,481.48 -5,355.01 1,532.80 6,022,418.11 535,160.69 4A3 4,331.99 2_MWD+IFR2+MS+Sag(1) 7,255.19 75.27 150.87 3,565.07 3,505.95 -5,435.23 1,575.28 6,022,338.09 535,203.54 2.63 4,412.86 2_MWD+IFR2+MS+Sag(1) 7,351.21 77.54 146.59 3,587.65 3,528.53 -5,514.96 1,623.72 6,022,258.58 535,252.33 4.94 4,498.33 2_MWD+IFR2+MS+Sag(1) 7,443.28 78.60 141.58 3,606.70 3,547.58 -5,587.89 1,676.55 6,022,185.90 535,305.48 5.45 4,583.48 2_MWD+IFR2+MS+Sag(1) 7,540.79 79.51 137.89 3,625.22 3,566.10 -5,660.92 1,738.42 6,022,113.16 535,367.68 3.83 4,676.08 2_MWD+IFR2+MS+Sag(1) 7,636.36 79.25 132.84 3,642.84 3,583.72 -5,727.74 1,804.39 6,022,046.64 535,433.94 5.20 4,768.47 2_MWD+IFR2+MS+Sag(1) 7,732.26 77.61 127.72 3,662.09 3,602.97 -5,788.47 1,876.03 6,021,986.24 535,505.85 5.50 4,862.00 2_MWD+IFR2+MS+Sag (1) 7,827.17 75.51 125.72 3,684.15 3,625.03 -5,843.66 1,950.01 6,021,931.39 535,580.07 3.02 4,954.26 2_MWD+IFR2+MS+Sag(1) 7,922.47 78.13 124.22 3,705.88 3,646.76 -5,896.84 2,026.04 6,021,878.57 535,656.33 3.15 5,047.04 2 MWD+IFR2+MS+Sag(1) 8,017.15 82.89 123.49 3,721.48 3,662.36 -5,948.84 2,103.57 6,021,826.92 535,734.09 5.08 5,140.38 2_MWD+IFR2+MS+Sag(1) 8,107.51 90.68 124.69 3,726.55 3,667.43 -5,999.37 2,178.23 6,021,776.73 535,808.96 8.72 5,230.51 2_MWD+IFR2+MS+Sag(1) 8,200.93 91.06 125.48 3,725.13 3,666.01 -6,053.06 2,254.66 6,021,723.40 535,885.63 0.94 5,323.92 2_MWD+IFR2+MS+Sag(2) 8,296.65 88.15 124.03 3,725.79 3,666.67 -6,107.62 2,333.29 6,021,669.20 535,964.50 3.40 5,419.62 2_MWD+IFR2+MS+Sag(2) 8,391.43 86.68 124.51 3,730.06 3,670.94 -6,160.93 2,411.54 6,021,616.24 536,042.98 1.63 5,514.29 2_MWD+IFR2+MS+Sag(2) 8,482.98 86.68 123.75 3,735.36 3,676.24 -6,212.21 2,487.19 6,021,565.31 536,118.86 0.83 5,605.67 2 MWD+IFR2+MS+Sag (2) 8,578.98 87.73 125.25 3,740.05 3,680.93 -6,266.52 2,566.21 6,021,511.37 536,198.11 1.91 5,701.55 2_MWD+IFR2+MS+Sag(2) 8,676.33 91.38 129.73 3,740.80 3,681.68 -6,325.74 2,643.42 6,021,452.50 536,275.58 5.94 5,798.77 2_MWD+IFR2+MS+Sag(2) 6/72019 12:58:57PM Page 4 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-18 Wellbore: MPU M-18PB2 Design: MPU M-18PB2 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU Mt -18 MPU M-18 Actual RKB @ 59.12usft MPU M-18 Actual RKB @ 59.12usft True Minimum Curvature NORTH US + CANADA MD Inc Azi TVD TVDSS +N/ -S +E/ -W Map Northing Map Easting DLS Vertical Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100-) (ft) Survey Tool Name 8,770.75 90.07 129.85 3,739.61 3,680.49 -6,386.16 2,715.96 6,021,392.41 536,348.39 1.39 5,892.86 2_MWD+IFR2+MS+Sag (2) 8,867.27 91.19 127.78 3,738.55 3,679.43 -6,446.66 2,791.16 6,021,332.27 536,423.85 2.44 5,989.16 2_MWD+IFR2+MS+Sag(2) 8,962.03 88.66 125.07 3,738.67 3,679.55 -6,502.91 2,867.39 6,021,276.36 536,500.33 3.91 6,083.88 2_MWD+IFR2+MS+Sag (2) 9,056.53 87.91 123.29 3,741.50 3,682.38 -6,555.98 2,945.53 6,021,223.66 536,578.70 2.04 6,178.32 2_MWD+IFR2+MS+Sag (2) 9,151.62 86.49 122.31 3,746.14 3,687.02 -6,607.42 3,025.36 6,021,172.57 536,658.75 1.81 6,273.22 2_MWD+IFR2+MS+Sag (2) 9,246.25 88.16 123.51 3,750.56 3,691.44 -6,658.78 3,104.71 6,021,121.58 536,738.33 2.17 6,367.68 2_MWD+IFR2+MS+Sag (2) 9,341.19 90.01 126.19 3,752.08 3,692.96 -6,713.02 3,182.61 6,021,067.70 536,816.46 3.43 6,462.59 2_MWD+IFR2+MS+Sag (2) 9,436.04 90.26 126.51 3,751.85 3,692.73 -6,769.24 3,259.00 6,021,011.84 536,893.10 0.43 6,557.42 2_MWD+IFR2+MS+Sag(2) 9,529.82 88.90 126.43 3,752.54 3,693.42 -6,824.98 3,334.41 6,020,956.44 536,968.75 1.45 6,651.16 2_MWD+IFR2+MS+Sag(2) 9,626.24 87.91 125.85 3,755.22 3,696.10 -6,881.82 3,412.25 6,020,899.96 537,046.84 1.19 6,747.53 2_MWD+IFR2+MS+Sag(2) 9,721.05 88.16 124.23 3,758.47 3,699.35 -6,936.22 3,489.82 6,020,845.91 537,124.65 1.73 6,842.28 2_MWD+IFR2+MS+Sag (2) 9,816.23 88.16 125.21 3,761.53 3,702.41 -6,990.40 3,568.01 6,020,792.09 537,203.08 1.03 6,937.41 2_MWD+IFR2+MS+Sag(2) 9,910.38 89.34 123.72 3,763.58 3,704.46 -7,043.67 3,645.62 6,020,739.18 537,280.91 2.02 7,031.53 2_MWD+IFR2+MS+Sag(2) 9,990.00 92.54 123.27 3,762.28 3,703.16 -7,087.59 3,712.00 6,020,695.56 537,347.48 4.07 7,111.09 2_MWD+IFR2+MS+Sag(3) 10,006.32 91.12 122.72 3,761.75 3,702.63 -7,096.48 3,725.68 6,020,686.74 537,361.20 9.35 7,127.39 2_MWD+IFR2+MS+Sag (3) 10,101.54 89.58 124.75 3,761.17 3,702.05 -7,149.35 3,804.86 6,020,634.23 537,440.61 2.68 7,222.58 2_MWD+IFR2+MS+Sag(3) 10,197.13 69.89 125.03 3,761.61 3,702.49 -7,204.03 3,883.26 6,020,579.91 537,519.26 0.44 7,318.17 2_MWD+IFR2+MS+Sag(3) 10,292.85 87.66 124.89 3,763.66 3,704.54 -7,258.86 3,961.69 6,020,525.44 537,597.92 2.33 7,413.86 2_MWD+IFR2+MS+Sag(3) 10,385.96 86.55 125.36 3,768.36 3,709.24 -7,312.36 4,037.74 6,020,472.29 537,674.21 1.29 7,506.85 2_MWD+IFR2+MS+Sag (3) 10,482.16 88.41 126.52 3,772.59 3,713.47 -7,368.77 4,115.55 6,020,416.24 537,752.26 2.28 7,602.94 2 MWD+IFR2+MS+Sag(3) 10,576.99 92.12 127.39 3,772.15 3,713.03 -7,425.77 4,191.31 6,020,359.59 537,828.28 4.02 7,697.70 2_MWD+IFR2+MS+Sag(3) 10,672.12 92.98 127.39 3,767.92 3,708.80 -7,483.48 4,266.82 6,020,302.23 537,904.04 0.90 7,792.66 2_MWD+IFR2+MS+Sag(3) 10,767.40 92.73 125.59 3,763.18 3,704.06 -7,540.06 4,343.33 6,020,245.99 537,980.79 1.90 7,887.78 2_MWD+IFR2+MS+Sag (3) 10,862.53 92.86 122.93 3,758.54 3,699.42 -7,593.55 4,421.85 6,020,192.87 538,059.54 2.80 7,982.78 2_MWD+IFR2+MS+Sag (3) 10,956.72 90.93 122.02 3,755.42 3,696.30 -7,644.09 4,501.26 6,020,142.69 538,139.18 2.27 8,076.82 2_MWD+IFR2+MS+Sag(3) 11,051.24 91.80 122.27 3,753.17 3,694.05 -7,694.37 4,581.27 6,020,092.78 538,219.40 0.96 8,171.19 2_MWD+IFR2+MS+Sag(3) 11,146.89 95.59 124.20 3,747.01 3,687.89 -7,746.67 4,661.09 6,020,040.84 538,299.45 4.44 8,266.57 2 MWD+IFR2+MS+Sag (3) 11,241.78 94.09 125.52 3,739.00 3,679.88 -7,800.71 4,738.67 6,019,987.16 538,377.27 2.10 8,361.11 2_MWD+IFR2+MS+Sag(3) 11,337.05 92.48 125.28 3,733.54 3,674.42 -7,855.80 4,816.20 6,019,932.42 538,455.03 1.71 8,456.22 2_MWD+IFR2+MS+Sag(3) 11,431.37 92.67 124.86 3,729.30 3,670.18 -7,909.94 4,893.32 6,019,878.64 538,532.39 0.49 8,550.45 2_MWD+IFR2+MS+Sag(3) 11,526.74 93.22 124.69 3,724.40 3,665.28 -7,964.27 4,971.55 6,019,824.67 538,610.86 0.60 8,645.69 2_MWD+IFR2+MS+Sag (3)M 11,622.77 94.16 124.76 3,718.22 3,659.10 -8,018.85 5,050.31 6,019,770.45 538,689.86 0.98 8,741.52 2_WD+IFR2+MS+Sag(3) 11,696.69 94.77 125.51 3,712.47 3,653.35 -8,061.27 5,110.58 6,019,728.31 538,750.31 1.31 8,815.21 2_MWD+IFR2+MS+Sag (3) 11,767.00 94.77 125.51 3,706.62 3,647.50 -8,101.96 5,167.61 6,019,687.88 538,807.52 0.00 8,885.28 PROJECTED to TD Checked By: Chelsea Wright.:_ w Approved By: Mitch Laird Date: 06-07-2019 61712019 12.:58:57PM Page 5 COMPASS 5000.15 Build 91 E Hilcorp Energy Company CASING & CEMENTING REPORT Lease &Well No. MPM-18 Date Run 28 -May -19 County State Alaska SUP, S. Sunderland I J. Vanderpool CASING RECORD Swhu � TD 8.162.00 Shoe Depth: 8,155.00 PBTD: 8.076.00 ,.aa -v nnwn: i9 iwy I ype Float Lollar Innovex No. Hrs to Run: 25.5 Casing (Or Liner) Detail 100.070 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg Setting Depths Jts. Component Size Wt. Grade Liner hanger test pressure: THD Make Length Batton Tap 1 Shoe 103/4 50.0 1 each onjoinM #5 to #25 then every otherjolnt to #137. Every joint from #139 to #149. TXP BTC -SR Innovex 1.47 8,155.00 8,153.53 2 Casing 95/8 1 40.0 L-80 I TXP BTC -SR Tenaris 79.90 8,153.53 8,073.63 1 Float Collar 103/4 50.0 TXP BTC -SR Innovex 1.30 6,073.63 8,072.33 1 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 39.32 8,072.33 8,033.01 1 Baffle Adapter 103/4 50.0 ig Rotated? TXP BTC -SR HES 1.61 8,033.01 8,031.40 140 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 5,518.39 8,031.40 2,513.01 1 Puploint 95/8 40.0 L-80 TXP BTC -SR Tenaris 13.49 2,513.01 2,499.52 1 ESIPC Cementer 103/4 TXP BTC -SR HES 10.10 2,499.52 2,489.42 1 Pup Joint 95/8 40.0 L-80 TXP BTC -SR Tenaris 11.70 2,489.42 21477.72 61 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 2,428.03 2,477.72 49.69 1 Cut Joint of Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 17.76 49.69 31.93 ,.aa -v nnwn: i9 iwy I ype Float Lollar Innovex No. Hrs to Run: 25.5 Csg Wt. Cm Slips: 100.070 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg X Yes _ No Recip Csg X Yes_ No 50 Ft Min, 94 PPG Fluid Description: Spud Mud Density (ppg) Liner hanger Into(Make/Madel): Liner lop Packer?: Yes No Liner hanger test pressure: Floats Held X Yes_ No Centralizer Placement 121 each 9-5/6" x 12-122Expand-o4izer centralizers ran. Lead 2 each with 4 stop rings on joint#1. 1 free floating on joint 42. 1 each onjoint #3 & 4 with 4 stop rings. Sacks: 885 Yield: -61r2 1 each onjoinM #5 to #25 then every otherjolnt to #137. Every joint from #139 to #149. 12 Volume pumped (BBLs) 1 each with 1 stop ring on each pupjoint above and below ESIPC between joints #143 & #144. 6 Autry Every other joint from #150 to #202. CEMENTING REPORT Shoe @ 8155 FC @ 8,07200 Top of Liner ush (Spacer) Clean Spacer Clean Spacer Density (ppg) Density (ppg) 10 Volume pumped (BBLs) 60 Slurry Lead Sacks: 885 Yield: -61r2 ity (ppg) 12 Volume pumped (BBLs) 371.2 Mixing / Pumping Rate (bpm): 6 Autry Tail Sacks: 4M 1.16 Ry (Ppg) 15Z Volume pumped (BBLs) -Yield: 82.4 Mixing / Pumping Rate (bpm): 3 Flush (Spacer) 'Pe: Density (ppg) Density(ppg) Rate (bpm): Volume: acement: Spud Mud Density (ppg) 9.4 Rate (bpm): 6 Volume (actual I calculated): 489.14/493.79 ;psi): 760 Pump used for tlisp: Rig Bump Plug? X YesNo Bump press 131C ig Rotated? X Yes _No Reciprocated? X Yes _No % Returns during job 100 )nt realms to surface? X Yes No Spacerretums? _ate: X Yes No Vol to Sun. 10 mt In Place At: 5:50 D 5292019 Estimated TOC: 2.489 A Used To Determine TOC: Returns to surface from FSIPr: Stage Collar@ 2489 Type ESIPC Closure OK Y re8ush (Spacer) /pe: Clean Spacer Density (ppg) 10 Volume pumped (BBLs) 60 :ad Slurry Fps: Permafrost L Sacks: 437 Yield: 4.41 onsity (ppg) 10.7 Volume pumped (BBLs) 383 Mixing / Pumping Rate (bpan): 4.1 .11 Slurry rye: Premium Sacks: 270 Yield'. 1.17 ensily (ppg) 158 Volume pumped (BBLs) 56.2 Mixing / Pumping Rate (bpm): 5 oat Flush (Spacer) 'Pe: Density (ppg) Rate (bpm): Volume: splacement: pe: Spud Mud Dowdy ppg) 94 Rate (bpm): 5 Volume (actual / calculated) : 168.77/169.1 ;P (psi): 480 Pump used for tlisp: Rig Bump Plug? X Yes _No Bump press 20 .sing Rotated? _Yes X No Reciprocated? Yes X No % Retums during job 100 amen realms to surface? X Yes No Spacerretums? X Yes Vol to Sun. 245 rment In Place At 15:4] Date: 5292019 _No EsSmatetl TOC: 34 athod Used To Determine TOC: Retums to surface CeICUlated Omt Vol @ 0% excess: 479.47 Total Volume cant Pumped: 89: Cmt returned to surface: 255 Calculated cement left in wellbore: 637.8 OH volume Calculated; 448.69 OH volume actual WT02 Actual % Washout 3529 MPU M-18 OH Sidetrack Summary PB1 PB2 TD 10,361' MD / 3,743' TVD 11,767' MD / 3,706' TVD KOP 9,990' MD 11,270' MD Date 6/2/2019 6/3/2019 PTD: 219-070 / API: 50-029-23632-00-00 Schwartz, Guy L (CED) From: Joe Engel <jengel@hiicorp.com> Sent: Tuesday, June 4, 2019 2:50 PM To: Schwartz, Guy L (CED) Cc: Cody Dinger Subject: RE: [EXTERNAL] RE: HAK MP M-18 (PTD: 219-070) Update #2 Hey Guy — Another M-18 drilling update. Drilling ahead in our 8.5" lateral yesterday we crossed a fault at 11260' MD that was OA3 to OA1, and subsequently drilling out of the top of the OA 1 at 11485' MD. To deliver our undulation targets we pulled back and performed an OH sidetrack at 11,270' MD. PB2 details below. OH Sidetrack Date Depth Interval (ft) Length (ft) PB1 6/2/2019 9990-10362 372 PB2 6/3/2019 11270 — 11767 497 Currently we are drilling the 8.5" Lateral at — 13,600' MD. Please let me know if you have any questions. Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Monday, June 3, 2019 10:55 AM To: Joe Engel <jengei@hilcorp.com> Subject: [EXTERNAL] RE: HAK MP M-18 (PTD: 219-070) Update NO questions... thanks for update. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwarfz@alaska.gov). From: Joe Engel <jengel@hilcorp.com> Sent: Monday, June 3, 2019 10:47 AM To: Schwartz, Guy L (CED) <guy.schwartz(a7alaska.eov> Subject: HAK MP M-18 (PTD: 219-070) Update Guy — I wanted to give you an update on M-18. While drilling the 8.5" lateral at 10,205' MD we drilled out of zone due to a formation dip angle change. The decision was made to pull back to 9990' MD and perform an OH sidetrack, PB1 information below. OH Sidetrack Depth Interval (ft) length (ft) PB1 9990-10362 372 Currently we are drilling the 8.5" Lateral at — 11,300' MD. Please let me know if you have any questions. Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 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 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU M-18 Hilcorp Alaska, LLC. Permit to Drill Number: 219-070 Surface Location: 4915' FSL, 561' FEL, SEC. 14, T13N, R9E, UM, AK Bottomhole Location: 844' FNL, 1795' FEL, SEC. 30, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development 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, Daniel T. Seamount, Jr. Commissioner DATED this" -7 day of May, 2019. RECEIVED STATE OF ALASKA AL/,_.A OIL AND GAS CONSERVATION COMMIS., ON PERMIT TO DRILL APR 2 6 2019 20 AAC 25.005 1a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas LJ Service - WAG LJ Service - Disp 01 c Specify if well is piop"psed for: Drill Lateral ❑ Stratigraphic Test ElDevelopment- 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 0 Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 • MPU M-18 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 16,722' TVD: 3,794' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: I Surface: 4915' FSL, 561' FEL, Sec 14, T13N, R9E, UM, AK (As Staked) ADL025514, ADL025515, ADL025517 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1128' FNL, 1669' FWL, Sec 24, T13N, R9E, UM, AK LONS 16-004 6/5/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 844' FNL, 1795' FEL, Sec 30, T13N, R10E, UM, AK 7659 4,152'to nearest unit boundary 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 59' 15. Distance to Nearest Well Open Surface: x- 533603 y- 6027765 Zone4 GL / BF Elevation above MSL (ft): 25.3' a to Same Pool: 650'to MPJ -20A 16. Deviated wells: Kickoff depth: 380 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.4 degrees Downhole: 1625 - Surface: 1257 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling I Length MD TVD MD TVD (including stage data) Cond 20" 215# X42 Weld 113' Surface Surface 113' 113' ±270 ft3 Stg 1 L - 1863.7 ft3 / T - 458 ft3 12-1/4" 9-5/8" 40# L-80 TXP SR 8,076' Surface Surface 8,076' 3,699' Stg 2 L - 1937 ft3 / T - 314113 Tieback 7" 26# L-80 TXP SR 7,926' Surface Surface 7,926' 3,685' Tieback Assy. 8-1/2" 6-5/8" 20# L-80 Hyd 563 8,796' 7,926' 3,685' 16,722' 3,794' Cementless Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑ No ❑4 20. Attachments: Property Plat O BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch e Seabed Report e Drilling Fluid Program a 20 AAC 25.050 requirementse 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'en el hIICOr .Com Authorized Title: Drilling Manager Contact Phone: 777-8395 Authorized Signature ---, Date: / • 21, commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: ot _ 07 50- 0 q .. — Date: ' 51 requirements. �,/ 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: L.1 Other: 1 Samples req'd: Yes ❑ NoW Mud log req'd: Yes[-] Nog' e-`�� HzS measures: Yes ❑ No Directional svy req'd: Yes[O' No❑� Spacing exception req'd: Yes [I No [� Inclination -only svy req'd: Yes❑ No Uy Post initial injection MIT req'd: Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 71) �/ ,/i+ ^��11 5' %_tl /�� /� ■ Submit Donn and (1/.�'y`¢ 10! Re�k�yletl /2017 Ute"'- This permit is valid for [V4 �n MoVm A�y`♦7*"e a proval r 20 , 5.005(g) Attachmems in Duplicate %�4f/�8 . s/s/iq H Hilc 4.26.2019 Commissioner Alaska Oil & Gas Conservation Commission 333 W. Th Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill MPU M-18 Joe Engel Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email: jengel@hilcorp.com Dear Commissioner, Hilcorp Alaska, LLC hereby submits for review and approval for a Permit to Drill an onshore production well at Milne Point'M' Pad, well slot 18. Drilling operations are intended to commence approximately June 5th, 2019, pending rig schedule. MPU M-18 is a grassroots jet pump producer planned to be drilled in the Schrader Bluff OA sand. M- 18 is part of a multi well program targeting the Schrader Bluff sand on M -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 6-5/8" liner will be run in the open hole section and the well produced with a jet pump assembly. The Doyon 14 will be used to drill and complete the wellbore. Please find attached the Form 10-401, Application For Permit to Drill per 20 AAC 25.005 (a) and the drilling program for MPU M-18, which includes information required by 20 AAC 25.005 (c). 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. �►p� P 7 0 �� Sincerely, oe Engel C G Drilling Engin r Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC Milne Point Unit (MPU) M-18 Drilling Program Version 1 4/26/19 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 R/U and Preparatory Work..........................................................................................................10 10.0 N/U 21-1/4" 2M Diverter System.................................................................................................11 11.0 Drill 12-1/4" Hole Section.............................................................................................................13 12.0 Run 9-5/8" Surface Casing...........................................................................................................16 13.0 Cement 9-5/8" Surface Casing.....................................................................................................21 14.0 BOP N/U and Test.........................................................................................................................26 15.0 Drill 8-1/2" Hole Section...............................................................................................................27 16.0 Run 6-5/8" Production Liner........................................................................................................31 17.0 Run 7" Tieback..............................................................................................................................36 18.0 Run Jet Pump Completion...........................................................................................................39 19.0 RDMO............................................................................................................................................40 20.0 Doyon 14 Diverter Schematic.......................................................................................................41 21.0 Doyon 14 BOP Schematic.............................................................................................................42 22.0 Wellhead Schematic......................................................................................................................43 23.0 Days Vs Depth................................................................................................................................44 24.0 Formation Tops & Information...................................................................................................45 25.0 Anticipated Drilling Hazards.......................................................................................................46 26.0 Doyon 14 Layout............................................................................................................................49 27.0 FIT Procedure................................................................................................................................50 28.0 Doyon 14 Choke Manifold Schematic..........................................................................................51 29.0 Casing Design.................................................................................................................................52 30.0 8-1/2" Hole Section MASP............................................................................................................53 31.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................54 32.0 Surface Plat (As Built) (NAD 27).................................................................................................55 33.0 Schrader Bluff OA Sand Offset MW vs TVD Chart..................................................................56 34.0 Drill Pipe Information 5" 19.5# 5-135 DS -50 & NC50...............................................................57 n Hilcorp mp 1.0 Well Summary Milne Point Unit M-18 SB Producer Drilling Procedure Well MPU M-18 Pad Milne Point "M" Pad Planned Completion Type Jet Pump on 3-1/2" Production Tubing Target Reservoir(s) Schrader Bluff OA Sand Planned Well TD, MD / TVD 16,721' MD / 3,793' TVD PBTD, MD / TVD 16,640' MD / 3,793' TVD Surface Location(Governmental) 365' FNL, 561' FEL, Sec 14, T13N, R9E, UM, AK Surface Location (NAD 27) X= 533603.8, Y= 6027765.6 Top of Productive Horizon (Govemmental) 11 28'FNL, 1669' FWL, Sec 24, TON, R9E, UM, AK TPH Location AD 27 X= 535865.9Y= 6021733.9 BHL Governmental 844' FNL, 1795' FEL, Sec 30, TON, R10E, UM, AK BHL (NAD 27) X= 542946.0, Y=6016774.9 AFE Number 1911313 AFE Drilling Das 23 days AFE Completion Das 5 days AFE Drilling Amount $4,811,775 AFE Completion Amount $1,993,932 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1257 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1625 psig Work String 5" 19.5# S-135 DS -50 & NC 50 KB Elevation above MSL: 33.7 ft + 25.3 ft = 59.1 ft GL Elevation above MSL: 25.3 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 2.0 Management of Change Information 11 Hilcorp Alaska, LLC Hilc rp Changes to Approved Permit to Drill Date: 412 612 01 9 Subject: Changes to Approved Permit to Drill for MPU M-18 File #: MPU M-18 Drilling and Completion Program Any modifications to MPU M-18 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AOGCC. Approval: Drilling Manager Date Prepared: Drilling Engineer pate Page 3 Milne Point unit M-18 SB Producer Hilco�Tfy� Ew wpm Drilling Procedure 2.0 Management of Change Information 11 Hilcorp Alaska, LLC Hilc rp Changes to Approved Permit to Drill Date: 412 612 01 9 Subject: Changes to Approved Permit to Drill for MPU M-18 File #: MPU M-18 Drilling and Completion Program Any modifications to MPU M-18 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AOGCC. Approval: Drilling Manager Date Prepared: Drilling Engineer pate Page 3 H Hileorp Em Cmnpmy 3.0 Tubular Program: Milne Point Unit M-18 SB Producer Drilling Procedure 4.0 Drill Pipe Information: All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • 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. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorl, ieneel@hilcorp.com and cdinger(a hilcoM.com 5.3 Intranet Home Page Morning Update • 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 • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Rud' Casing tally to mmyers m,hilcoM,com iengel@hilcoip.com and edinger@hilcoM.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mLnyers@hilcoip.com hilcoip.com iengel@hilcorp.com and cdinger@hilcoEp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Milne Point unit 907.777.8431 907.538.1168 mmyers@hilcorp.com M-18 SB Producer Joe Engel Hilmix Evyy Campuy Drilling Procedure 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • 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. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, mmyers@hilcorl, ieneel@hilcorp.com and cdinger(a hilcoM.com 5.3 Intranet Home Page Morning Update • 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 • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Rud' Casing tally to mmyers m,hilcoM,com iengel@hilcoip.com and edinger@hilcoM.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mLnyers@hilcoip.com hilcoip.com iengel@hilcorp.com and cdinger@hilcoEp.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 lengel@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.947.9533 twellman@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caaones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger hilcorp.min Page 5 N Hilcorp E� Qvpq 6.0 Milne Point Unit M-18 SB Producer Drilling Procedure Planned Wellbore Schematic pUJCR t N%f Og 0 Ea.:-w/Ci Eel: w M=1A7M! l/m=47Mr,q P82D=14717 IN" IM=3,9-O M)j Page 6 Milne Point Unit Well: MPU Moose Pad M-18 PROPOSED SCHEMATIC Last Completed: Proposed PTD: TBD ---------------------------------- TREE& WELLHEAD Tree 1 Camera.3 LT SM W.11h d PRK lI"SMtt-]Aw/11'x31,2'7[-11 Too ab BptLLm Turing Ilwyl.fth 3'OW"'11'BWomfik. 2ea 3/8'NPI rvM llines. OPEN HOLE / CEMENT DEW 42' WbW pOYards Qj�4LedompNdpNnfiakridel 12-1(b'1st Nage L-191S3.I ft3/T-45B f13 12-1(d"2rM Nage L -193703/7-314U &112- Ct'vcol4'w Prcwlea Nner ln8-1R"hok 1C8 @ 380' Max Ilpk An le=p kt PumO Max Iluk An qe=� #1 prprik Max lluk Angle e,&Tuhi -fail Maa Ilok Angle=89A '--•---�---------- I _ _ --- .---------- ---------------------••-_-------------- --_ -- --- --------- 1EWELRYDETAIL W. I Tp MD teem Dn0@ upxrCo ktion 1 29 7P6in Ilann13.1(2'TC-II Too&kW v/B ffinp on han PUP 2867' 2 •1.315' 35"GiMw11.S"SOGLYaet ;600 aMxr 2867" 3 e7,M 3.5"DiulsWPr ,s Gauge Mandrel lOxharge Gsugel 227V 4 17,6W 3.5"fm Sraln 51e 2.813"Pukin B 2913" S e7.W 3.5"G 9u Abndrel W V Wm p nwke Cmu 1 2975" 6 J,M 3.S%Nipple 12.813'Pekin Basel 2.813' 7 =7.= 1 x 3.5' PI IL AelricvaGe PaO r 450 Sfi r9eleme 22W B e],EW 3.S"%N Nip* 12813" Park" Wre:27V N"D)W0 VW W*tee 275P 9 J,S00 3.S WO:G 2867' luwer[Pnole[im 10 7,9M' BOT SMP Liner Top Parker wMD Lips 7 - Sir .. sw &1]U' 11 7.926' YTcWkAss _ 1825' WN,f) 6.151" 12 71915' 7ta,U K3 LW x6-5/rV d,,AM3 L-Y1%O 3926' 13 7,865' &W 51oteed liner 5921" 16 1 16,722' 1 Shm -------------- ______----------------------------- GENERAL WELL INFO API:TBD Ddlka anaunrolnea D 34-reo H Hilcrp U-27 7.0 Drilling / Completion Summary Milne Point Unit M-18 SB Producer Drilling Procedure MPU M-18 is a grassroots jet pump producer planned to be drilled in the Schrader Bluff OA sand. M-18 is part of a multi well program targeting the Schrader Bluff sand on M -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 6-5/8" slotted liner will be run in the open hole section and the well produced with a jet pump assembly. The Doyon 14 will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately June 5th, 2019, pending rig schedule. Surface casing will be run to 8,076 MD / 3,698' 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 Doyon 14 to well site 2. NIU & Test 21-1/4" 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. N/D diverter, N/U & test 13-5/8" x 5M BOP 5. Drill 8-1/2" lateral to well TD. Run 6-5/8" production liner 6. Run 7" tieback 7. Run completion 8. N/D BOP, N/U 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 7 H Hilcorp Ew ®puY Milne Point Unit M-18 SB Producer 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. • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU M-18. Ensure to provide AOGCC 24 Ins notice prior to testing BOPs. • 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. • 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. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • 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 • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: No variances are requested at this time. Page 8 n Hilcorp Eo�y c�pmy Summary of BOP Equipment & Notifications Milne Point Unit M-18 S8 Producer Drilling Procedure Hole Section Equipment Test Pressure(psi) 12 1/4" • 21-1/4" 2M Diverter w/ 16" Diverter Line Function Test Only • 13-5/8" x 5M Hydril "GK" Annular BOP Initial Test: 250/4j961f • 13-5/8" x 5M Hydril MPL Double Gate o Blind ram in btm cavity 3eto • Mud cross w/ 3" x 5M side outlets 8-1/2" 13-5/8" x 5M Hydril MPL Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250L4Qe • 3-1/8" x 5M Choke manifold 3CZ"0 • Standpipe, floor valves, etc Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. W 1 Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email:,jim.regg(a)alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: gpy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectorsaalaska.gov Test/Inspection notification standardization format: hiip:Hdoa.alaska.gov/ogc/forms/TestWitnessNotif.htmi Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 9.0 R/U and Preparatory Work Milne Point Unit M-18 SB Producer Drilling Procedure 9.1 M-18 will utilize a newly set 20" conductor on M -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 R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Doyon 14. 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 (<80°F). 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Ensure 6" liners in mud pumps. • Continental EMSCO FB -1600 mud pumps are rated at 4665 psi, 462 gpm @110 spm @ 95% volumetric efficiency. Page 10 H Hilcorp U� 10.0 N/U 21-1/4" 2M Diverter System Milne Point Unit M-18 5B Producer Drilling Procedure 10.1 N/U 21-1/4" Hydril MSP 2M Diverter System (Diverter Schematic attached to program). • NIU 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter "T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. 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: • A prohibition on vehicle parking A prohibition on ignition sources or running equipment A prohibition on staged equipment or materials Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page I1 0 HilcoT � , 10.5 Rig & Diverter Orientation: • May change on location M-10 M-11 M-13 ■ M-12 X M-14 ■ M-20 0 M-15 ■ M-21 M-16 ■ M-22 M-17 M-18 M-19 75' Radius Clear of I¢nition Sources Milne Point Unit M-18 SB Producer Drilling Procedure Diverter Line Drawing Not To Scale MPU M -Pad Diverter Line May Be Oriented Different On Location Page 12 H Hilcorp 11.0 Drill 12-1/4" Hole Section Milne Point Unit M-18 SB Producer Drilling Procedure 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# 5-135. • 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. • Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4" hole section to section TD, in the Schrader OA sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • 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 • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • 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. • 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). • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. Page 13 n Hilcorp Milne Point Unit M-18 SB Producer Drilling Procedure • Gas hydrates have not been seen on M -Pad. However, be prepared for them. In MPU they have been encountered typically around 2100-2400' TVD (just below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Past wells on E pad have increased MW to 9.8 ppg and added 1-1.5ppb of Lecithin & .5% lube. After drilling through hydrate sands, MW was cut back to normal • 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. • 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. 11.4 12-1/4" hole mud program summary • 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. Depth Interval MW g) 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 • 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. • 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. • 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. • 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. Page 14 H Hilcrp U r22_ Milne Point Unit M-18 SB Producer Drilling Procedure • 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 — 9.2 ppg Pre -Hydrated Aquagel/freshwater spud mud Pro erttes: Section Density Viscosity Plastic Vtscosi Yield Point API FL H Tem Surface 8.p 9.8 1 75-175 1 20-40 1 25-45 <10 8.5 — 9.0 S 70 F System Formulation: Gel + FW spud mud Product- Surface hole Size Pkg ppb or (% liquids) M -I Gel 50 Ib sx 25 Soda Ash 50 Ib sx 0.25 Pol Pac Supreme UL 50 Ib sx 0.08 Caustic Soda 50 lb sx 0.1 SCREENCLEEN 55 gal dm 0.5 11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.6 RIH t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 —10 ft / minute, adjust as dictated by hole conditions • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No open hole logging program planned. Page 15 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & 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 w/ stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint w/ 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 • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle WO • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. J Page 16 Milne Point Unit M-18 SB Producer HilHilcorp Cmnyny Drilling Procedure 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & 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 w/ stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint w/ 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 • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle WO • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. J Page 16 n Hilcorp e—x,� 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No. Closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth Baffle Adapter (if used) ID Depth Bypass or Shut-0ff Baffle to Depth Float Collar Depth Float Shoe Depth Hole TD "Reference Casing Sales Manuel Sec 5 Page 17 ^A Overall Length 8 Mn. 10 After Drilbut C Max. Tool OD D Opening Seat ID E Closing Seat ID Plug Set Part No. SO No. Closing Plug OD Opening Plug OD OD Shut-off Plug OD Bypass Plug (if used) DD Milne Point Unit M-18 SB Producer Drilling Procedure PFA 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: • 1 centralizer every joint t/ — 1000' MD from shoe • 1 centralizer every 2 joints to —2,000' above shoe (Top of Ugnu) • Verify depth of lowest Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH 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). (Halliburton ESIPC with packer element may be used). • Install centralizers over couplings on 5 joints below and 55 Joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/8" 40# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs Milne Point Unit 23,060 ft -lbs M-18 SB Producer Hilcorp U Drilling Procedure 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: • 1 centralizer every joint t/ — 1000' MD from shoe • 1 centralizer every 2 joints to —2,000' above shoe (Top of Ugnu) • Verify depth of lowest Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH 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). (Halliburton ESIPC with packer element may be used). • Install centralizers over couplings on 5 joints below and 55 Joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/8" 40# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Page 18 TXPO BTC Ourhi tle Diameter 9.625 in. Min. wall Milne Point Unit Make-up Loss 6.891 in. Threa9s per in M-18 SB Producer Hill; o Drilling Procedure TXPO BTC Ourhi tle Diameter 9.625 in. Min. wall 97.5% Make-up Loss 6.891 in. Threa9s per in 5 Ci nnec6on OD Option REGULAR PERFORMANCE Thil,lina s Tatum F flartr, 100.0% strength I'I Gentle LBO lbs Canpressbn Efioiency 100% Compression snengih 916 000 x1000 Max. Allowable Bending 38 °11009 Type 1 Wall Thickness 0.395 in. Connection OD REGULAR Lnnnum 18860 ft- Optimum 20960 ft4bs Maximum 23069 h -IDs OPERATION LIMIT TORQUES Option Operadig T.Q. 35600 R -lbs Yield Tongue COUPLING Notes This connection is fully interchangeable with: TXPO BTC - 9.625 in- - 36143.5147153.5158.4 lbs/ft Eody.Red internal pressure leak resistance as per section 10.3 API Grade L80 TYPO 1' Drift API S1arWard 1st sand: a. 2nd Band. - Type Casirq 3rd Band. - PIPE BODY DATA GEOMETRY Nominal OD 9.625 in. PAsminal Weight 40 lbsM Ddh Nominal ID 8.935 in Was ThiOAesa 0.395 in Plain End weight OD Tolart. APJ 11w.... 1110812018 low PIPE BODY 1st Band: Red 2nd Band: Brown 3rd sand - a1h Band: - PERFORMANCE Body Yxdd5aength 916x10008n Imerna:Yadd 5750 pili sMYs 80000 psi Collapse 3090 psi GEOMETRY Cc,rver m OD 10.625 in. Coupling LengA 10825. connection ID 8.823 in. Make-up Loss 6.891 in. Threa9s per in 5 Ci nnec6on OD Option REGULAR PERFORMANCE Tatum F flartr, 100.0% strength 916.000x1000 Internal Pressure Capacity Ill 5750000 psi lbs Canpressbn Efioiency 100% Compression snengih 916 000 x1000 Max. Allowable Bending 38 °11009 ICs Ecemal P... Capacity 3090.000 ps MAKE-UPTORQUES Lnnnum 18860 ft- Optimum 20960 ft4bs Maximum 23069 h -IDs OPERATION LIMIT TORQUES Operadig T.Q. 35600 R -lbs Yield Tongue 43800 hobs Notes This connection is fully interchangeable with: TXPO BTC - 9.625 in- - 36143.5147153.5158.4 lbs/ft [1] Internal Pressure Capacity related to structural resistance only. internal pressure leak resistance as per section 10.3 API 5C3/ ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Tenans technical sales representative. Page 19 n Hilcorp E. Milne Point Unit M-18 SB Producer Drilling Procedure 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 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 P/U landing joint and M/U 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 M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 20 n Hilcorp F uflY � P�^Y 13.0 Cement 9-5/8" Surface Casing Milne Point Unit M-18 SB Producer Drilling Procedure 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. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement pump. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • 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 • Review test reports and ensure pump times are acceptable. • 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/TJ 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 15` 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 I" Stage Total Cement Volume: Page 21 act `l nK IN Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" (7,076'- 2500') x .0558 bpf x 1.3 = 331.9 1863.7 J Casing Total Lead '1.3 331.9 1863.7 12-1/4" OH x 9-5/8" (8,076'- 7,076') x.0558 bpf x 1.3 = 72.5 407 Casing ~ 9-5/8" Shoe Track 120'x.0758 bpf = 9.1 51.09 Total Tail !f� 81.6 458 Page 21 act `l nK IN n Hilcorp Milne Point Unit M-18 SB Producer 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. • 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: 7,956' x .0758 bpf = 603.1 bbls 40 bbls of weighted spacer to be left behind stage tool, confirm spacer is compatible with cement behind stage tool & that sufficient spacer will be above the tool to exit when circulation is established. Consider pumping more spacer. 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, f4.5 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. Page 22 f Lead Slurry Tail Slurry System ExtendaCEM'm System SwiftCEM'm System Density 11.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed Water 21.13 gal/sk 5.04 gal/sk 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. • 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: 7,956' x .0758 bpf = 603.1 bbls 40 bbls of weighted spacer to be left behind stage tool, confirm spacer is compatible with cement behind stage tool & that sufficient spacer will be above the tool to exit when circulation is established. Consider pumping more spacer. 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, f4.5 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. Page 22 f n Hilcorp Milne Point Unit M-18 SB Producer 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 3300 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. If ESIPC is ran, pressure up to 3000 psi to open tool and function as an ES -II stage tool 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 23 n Hilcorp �=TJ Second Stage Surface Cement Job: Milne Point Unit M-18 SB Producer Drilling Procedure 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2"d stage is ready. Hold pre job safety meeting. • Past wells have seen pressure increase while circulating through stage tool after reduced rate 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 2"d 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 2"d Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM TM System (Hal Cem) 20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 v 12-1/4" OH x 9-5/8" Casing (2000'- 110') x .0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 12-1/4" OH x 9-5/8" Casing (2500'- 2000') x .0558 bpf x 2 = 55.8 314 ~ Total Tail 55.8 314 Cement Slurry Design (2nd stage cement job): Page 24 Lead Slurry Tail Slurry System Permafrost L SwiftCEM TM System (Hal Cem) Density 10.7 Ib/gal 15.8 lb/gal Yield 4.3279 ft3/sk 1.16 ft3/sk Mixed Water 21.405 gal/sk 5.08 gal/sk Page 24 H Hilcorp e� -R Milne Point Unit M-18 SB Producer 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 .0758 bpf = 190 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 1000 — 1500 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: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. 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 iengel hilcoW.eom and cdinizerghilcorp. com This will be included with the EOW documentation that goes to the AOGCC. Page 25 H HilcoT ...'Y CIL 14.0 14.1 14.2 14.3 Milne Point Unit M-18 SB Producer Drilling Procedure BOP N/U and Test N/D the diverter T, knife gate, diverter line & N/U I1" x 13-5/8" 5M casing spool. N/U 13-5/8" x 5M BOP as follows: • 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 • Double gate ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in bottom cavity. • Single ram can be dressed with 2-7/8" x 5" VBRs • N/U bell nipple, install flowline. • Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual valve RU MPD RCD and related equipment 14.4 Run 5" BOP test plug 14.5 Test BOP to 2500/psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Test 5" tes-- t�oints Confirm test vrressures with PTD Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.6 R/D BOP test equipment 14.7 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.8 Mix 8.9 ppg F1oPro fluid for production hole. 14.9 Set wearbushing in wellhead. 14.10 If needed, rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.11 Ensure 6" liners in mud pumps. Page 26 ff Hilcorp M Campuy 15.0 Drill 8-1/2" Hole Section 15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM) Milne Point Unit M-18 S8 Producer Drilling Procedure 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM 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 RX and test casing to 2500 psi / 30 in. Ensure to record volume / pressure (every ''/a bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5750 / 2 = --2875 psi, but max test pressure on 'a 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 Gy� 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 12.0 p�EMW. Chart Test. Ensure test is recorded on same chart as FIT. C l Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH & LD Cleanout BHA 15.9 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/J and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135 DS50 & NC50. • Run a ported float in the production hole section. 15.10 8-1/2" hole section mud program summary: • 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. Use appropriate SAFECARB blend on this well Page 27 • 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. • 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 sufficient hole cleanin>= • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Toteo 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 FloPro drilling fluid Properties: Interval Density Milne Point Unit YP LSYP Total Solids M-18 SB Producer HPHT HHilco�TTy1 l c®pmy Drilling Procedure • 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. • 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 sufficient hole cleanin>= • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Toteo 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 FloPro drilling fluid Properties: Interval Density PV YP LSYP Total Solids MBT HPHT Hardness Production 8.9-9.5 1 15-25 - ALAP 1 15-30 4-6 1 <10% <g I <11.0 1 <100 System Formulation: Product- production Size Pkg ppb or (% liquids) Susan 1060 55 gal dm 0.095 FLOTROL 55 lb sx 6 CONQOR 404 WH (8.5 gall 100 bbls) 55 gal dm 0.2 FLO-VISPLUS 25 lb sx 0.7 KCl 50 lb sx 10.7 SME 50 lb sx 0.45 LOTORQ 55 gal dm 1.0 SAFE -CARS 10 (verify) 50 lb sx 10 SAFE-CARB 20 (verify) 50 lb sx 10 Soda Ash 50 lb sx 0.5 Page 28 H Hilcorp E� C.P., 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Flo Pro drilling fluid Milne Point Unit M-18 SB Producer Drilling Procedure 15.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 15.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • 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. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • 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. • Use ADR to stay in section. Reservoir plan is to undulate between Schrader OAl & OA3 lobes in 1000-1500' MD increments, and keeping DLS <3° when moving between lobes • 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. • Target ROP is as fast as we can clean the hole without having to backream connections • Schrader Bluff OA Concretions: 5-10% of lateral • L-47:6%, L-50 9.5% • F-106: 6.1%, F-107: 4.7%, F-018: 9.9%, F-109: 10%, F-110: 10.1% • Offset injection and abnormal pressure has been seen on M-10, -11, -12. MPD will be utilized to monitor pressure build up on connections. — • Close Approaches: • J-24: 15400' MD. J-24 is an abandoned SB OA well, any collision risk is off% minimal due to abandoned lateral. J -24A is an active SB NB injector. There is minimal risk with J -24A. • Fluid Loss: • M-14: Drilling 8.5" lateral – 1500' away from J-24, losses were incurred, and subsequently healed with LCM pills. Suspect depleted reservoir near J-24. Consider adding background LCM – 2000' away from J-24, and lower flow rate. Have LCM ready if pills are necessary Page 29 15.15 Reference: Open hole sidetracking practice: • 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. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. L� 4t) 4 L � ? 60 S`T-, c 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • Ensure mud has necessary lube % for running liner • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 15.17 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (less if losses are seen, 385 gpm min). • Rotate at maximum rpm that can be sustained. • Pulling speed 5 — 10 min/std (slip to slip time, not including connections), adjust as dictated by hole conditions • If backreaming operations are commenced, continue backreaming to the shoe 15.18 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOK 15.19 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. 15.20 Monitor well for flow / monitor for pressure build up with MPD. Increase mud weight if necessary 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 15.21 POOH and LD BHA. 15.22 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, 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 30 Milne Point unit M-18 SB Producer Hilco =2 Drilling Procedure 15.15 Reference: Open hole sidetracking practice: • 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. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. L� 4t) 4 L � ? 60 S`T-, c 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • Ensure mud has necessary lube % for running liner • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 15.17 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (less if losses are seen, 385 gpm min). • Rotate at maximum rpm that can be sustained. • Pulling speed 5 — 10 min/std (slip to slip time, not including connections), adjust as dictated by hole conditions • If backreaming operations are commenced, continue backreaming to the shoe 15.18 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOK 15.19 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. 15.20 Monitor well for flow / monitor for pressure build up with MPD. Increase mud weight if necessary 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 15.21 POOH and LD BHA. 15.22 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, 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 30 H Hilcorp �Pay 16.0 Run 6-5/8" Production Liner Milne Point Unit M-18 SB Producer Drilling Procedure 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 6- 5/8" pre drilled liner, the following well control response procedure will be followed: • P/U & M/U the 5" safety joint (with 6-5/8" crossover installed on bottom, TIW valve in open position on top, 6-5/8" handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 6-5/8" Predrilled liner. • Slack off and with 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW. • Proceed with well kill operations. 16.2 Well control igparadness: In the event of an influx of formation fluids while running the 3- 1 mne/Z'r er string inside the 6-5/8" pre drilled liner: • P/U & M/U the 5" safety joint (with 6-5/8" x 3-1/2" triple connect crossover installed on bottom, TIW valve in open position on top, 3-1/2" handling joint above TIW). M/U 3-1/2" and then 6-5/8" to triple connect. • This joint shall be fu y1� with crossovers prior to running the first joint of wash pipe. • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. Proceed with well kill operations. 16.3. Pick up and rack back as much 3-1/2" inner string as possible. Ensure to check over pull limitations with drill pipe in the derrick. 16.4. R/U 6-5/8" liner running equipment. • Ensure 6-5/8" 20# Hydril 563 x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 16.5. Run 6-5/8" slotted production liner • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run packoff and float shoe on bottom. • 6-5/8" slotted liner will auto —fill • 6-5/8" Liner will be centralized with I/joint free floating • If needed, install swell packers as per the lower completion tally. • Remove protective packaging on swell packers just prior to picking up • Do not place tongs or slips on the packer element 6-5/8" 20 # Hydril 563 Torque OD Minimum Optimum Maximum Yield Tor ue 6-5/8 5,900 ft -lbs 7,100 ft -lbs 10,300 ft -lbs 36,000 ft -lbs Page 31 ff Hilc=Eovp' Cmpey Wedge 563® Page 32 Milne Point Unit M-18 SB Producer Drilling Procedure n.....11A)W2ot8 Olrtside D..". &82511. Min. Wall 875`:, Gannacm,ce r.35m �n Thickneaa 935 m. j')Grada L80 SAID A1aLcup Lvs 4.GWE Tnnv]spa, in 339 Type 1 RYGUI R.. Wall Thicknexa pZ80 n. CDime6.01) REGULAR Tefs✓io ED[vm} 95..i^. Option a393b]a1DJJ C01FUNG mPEaCOY ILS Socy. Rad td aann. Red Grade Lee Type v One API Standard 14 Sand: Brown 2rd 13 - . 15s 2nd Sand. • Brown EaWrnal:Yessuro Lapa:Ih waAw pan Type Gflne 3rd Sand Sd Sdnd. MAKE-UP TORQUES 4th R Ild. PIPE BODY DATA GEOMETRY Npmina100 fi.f251n. M0 i.1wm'N NpmlpaJc EM9:n. 40 TFYnpSs ODTGDnncc API PERFORMANCE EIX'Y01d sv.,IL 459a1G00IGs YMmtl bald talar -a San cnl CONNECTION DATA 20M Ibdl 001t 5.9241n. 0.1081.. Alam End l 9 1 10S, "x n 6090 (al SNv'S 00000x1 GEOMETRY_ ___. Gannacm,ce r.35m �n Oaupmg Lan?m 935 m. cmnu.ls:1D SAID A1aLcup Lvs 4.GWE Tnnv]spa, in 339 Canns[IiWn np GCaC. RYGUI R.. PERFORMANCE Tefs✓io ED[vm} 95..i^. Jtlnl YmlE aksnp:' a393b]a1DJJ VMmal Peessum 4apa[p 6090_(90 px ILS Gpmpmssun EOca ry 100.04: GDmpresziOn EnpnOn 459..000.1000 fi AraS OarAEq SZE - Awls 15s EaWrnal:Yessuro Lapa:Ih waAw pan GDODIr9Pace Load 318000 L5 MAKE-UP TORQUES ummum 59WTI. 90mum 7100 SU4mum f0Y10tb, OPERATION UMIT TORQUES Opmau-q TUWO 310001LIGs Yien Tarqua 3609Dtl.lGs BUCK -ON Mdmum 90000 irILs Na•imum 11304 a-mz Notes This wnnection is fLdty interchangeablie with Wedge 5638 - fi 625 in. - 24128? 32 Ito7fi Connections w1h Dopelesse Technology am tu8y compatible with the same connection in its Standard version H Hilcorp Milne Point Unit M-78 SB Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for approx 150' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8" connection. • Consider having a Joint of solid pipe across BOPE Stack while running inner string 16.7. R/U false rotary and run 3-1/2" 94 Inner String • Ensure inner string is drifted for WIV closing ball OD 16.8. Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.9. M/iJ Baker SLZXP liner top packer to inner string and 6-5/8" liner. 16.10. Note PUW, SOW, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH w/ liner on 5" HWDP no faster than 30 ft/min — this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. • Ensure 5" HWDP has been drifted 16.12. The inner string will prevent the DP from auto filling. Fill DP with mud every 5 stands, more frequently if SOW trend indicates. 16.13. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.14. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 rpm 16.15. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.16. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.17. Rig up to pump down the work string with the rig pumps. NOTE: The wellbore will be swapped over to brine after the liner has reached TD to remove mud cake from the well bore. Mud cake will cause facility upsets. Page 33 16.18. Break circulation and circulate out the mud. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. Displace well to brine (-9.2 ppg KCl/NaCI). , over displace well by at least 100+ bbl. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. 16.19. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the swell packers (if run). Do not exceed 1,600 psi while circulating as noted above. Note all losses. Confirm all pressures with Baker. 16.20. 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. 16.21. Displace 1.5 OH + Liner volume. 16.22. 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. 16.23. Shut down pumps. 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. Chase setting ball down with 20bb1 HV pill 16.24. Continue pressuring up to 2700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the ZXP liner hanger to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4500 psi to release the HRDE running tool. 16.25. Bleed DP pressure to zero. Pick up to expose Rotating Dog Sub and set down 50k# without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k# again, 16.26. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.27. 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. 16.28. P/U pulling 3-1/2" out of the pack off & displace out liner with two volumes at max rate. 16.29. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. L/D 3-1/2" inner string. Leave enough 5" DP racked back to trip back to 9- 5/8" shoe. Page 34 Milne Point Unit M- 18 SB Producer Bile o Eos C22 Drilling Procedure 16.18. Break circulation and circulate out the mud. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. Displace well to brine (-9.2 ppg KCl/NaCI). , over displace well by at least 100+ bbl. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. 16.19. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the swell packers (if run). Do not exceed 1,600 psi while circulating as noted above. Note all losses. Confirm all pressures with Baker. 16.20. 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. 16.21. Displace 1.5 OH + Liner volume. 16.22. 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. 16.23. Shut down pumps. 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. Chase setting ball down with 20bb1 HV pill 16.24. Continue pressuring up to 2700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the ZXP liner hanger to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4500 psi to release the HRDE running tool. 16.25. Bleed DP pressure to zero. Pick up to expose Rotating Dog Sub and set down 50k# without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k# again, 16.26. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.27. 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. 16.28. P/U pulling 3-1/2" out of the pack off & displace out liner with two volumes at max rate. 16.29. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. L/D 3-1/2" inner string. Leave enough 5" DP racked back to trip back to 9- 5/8" shoe. Page 34 H Hilcorp Em Cm , Milne Point Unit M-18 SB Producer Drilling Procedure 16.30. M/U 3.5" wash tool & RIH w/ remaining DP out of derrick to liner top. 16.31. Wash through liner top at max rate & circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. 16.32. POOH & L/D remaining 5" HWDP & Inner string 16.33. Once inner string is L/D, swap to the completion AFE Page 35 17.0 Run 7" Tieback Milne Point Unit M-18 SB Producer Drilling Procedure 17.1 RIH with mule shoe on 5" DP to Liner Top and circulation Liner Top and SBE clean. POOH. 17.2 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie -back space out calculation. Install and test 7" (250/3000 psi) solid body casing rams. 17.2 R/U 7" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. Rig up computer torque monitoring service. String should stay full while running, r/u fill up line and check as appropriate. 17.3 PIU tieback seal assembly and set in rotary table. Ensure 7" seal assembly has x4 1" holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7" annulus. 17.4 M/U first joint of 7" to seal assy. 17.5 Run 7" 26# TXP tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. Page 36 ff Hilcorp e^m8f 1,22- TXPO BTC Outside Diameter 7.000 in. Wall Thickness 0.362 in. Grade LBO Type t - PIPE BODY Cl:T . GEOMETRY Nominal OD 7.000ia Nominal ED 6276in. Min. Wall Thickness Connection DD Option Drift Type Nominal Weight Wall Thickness Milne Point Unit M-18 SB Producer Drilling Procedure --- 12'06.'2018 87.5% (') Grade LBB GEOMETRY Type 1 REGULAR Connection OD Makeup Loss CWPLING PIPE BOGY 1D.2DO in. 5 Fatly: Red 1st Band: Red All Standard 1st Band: Brown 2nd Band: 2nd Band: - Brown Caning 3rd Band:- 3ndBand :- &K -00D zlODO lbs 601-000ilX0 lbs Ineemal Pressare Capacity 0l Max. AllowaLie Bening 4th Band - 261bs7t Dnfl 0.362 in. Plan EM Weight 6.15t . 25.69 is ft OD Tolerance API PERFORMANCE Body Yield Strength 604:1000[be Internal Yield 7240 poi BUYS 80000 psi Collapse 5410 psi CONNECTION DATA GEOMETRY Connection OD Makeup Loss 7.656 in 4376 in. Co*ing Levy h Threads per in 1D.2DO in. 5 Connection ID Connection OD Option 6.261 n REGULAR I PERFORMANCE Ten= -ion Efrnczhcy Compression EPncrcy External Pressure Capacity 100.0% 100% 541OD00psi Joint Yield Strength Compression Strength &K -00D zlODO lbs 601-000ilX0 lbs Ineemal Pressare Capacity 0l Max. AllowaLie Bening 7240.000 psi 52'11000 MAKE-UP TORQUES h6nimum 13280 ft-bs Cptanun 1475064bs Maamw 162306-M OPERATION LIMIT TORQUES Operating T-nlue 20001 Yield Torque 234000 -lbs Notes This connection is fully interchangeable With: TXPtID BTC - 7 in. - 23129 J 32135 J 38 IbsM [t] Internal Pressure Capacity related to structural resistance only. Interrai pressure leak resistance as per section 10.3 API 5C3 I ISO 10400 - 2007. Page 37 n Hilcorp 17.6 M/U 7" to DP crossover. Milne Point Unit M-18 SB Producer Drilling Procedure 17.7 M/U stand of DP to string, and M/U top drive. 17.8 Break circulation at 1 bpm and begin lowering string. 17.9 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 17.10 Continue lowering string and land out on no-go. Set down 5 — l0k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 17.11 P/U string & remove unnecessary 7" joints. 17.12 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 17.13 Ensure circulation is possible through 7" string. 17.14 RU and circulation corrosion inhibited brine in the 9-5/8" x 7" annulus. 17.15 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7" x 9-5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7", verify collapse pressure of 7" tie back. 17.16 Slack off and land hanger. 17.17 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 17.18 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 17.19 R/D casing running tools. 17.20 Test 7" x 9-5/8" production annulus to 1000 si / 0 min. dA 17.3 Set test plug and change top rams from 7" to 2-7/8" x 5-1/2" VBR. Test annular and lower rams to 2-7/8" test joint, 250 low / 3000 psi high. Page 38 H Hilcorp 18.0 Run Jet Pump Completion Milne Point Unit M-18 SB Producer Drilling Procedure 18.1 Change upper pipe rams back to 2-7/8" x 5" VBR. Test same. Verify the Jet pump components. 18.2 Run the 3-1/2" Jet Pump Completion as noted by completion engineer. a. Jet pump will be reverse circulating 18.3 M/U Jet Pump assembly and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 18.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.5 MU tubing hanger and landing joint. Terminate control lines. 18.6 Land tubing hanger. 18.7 Drop ball and rod, pressure up to 1,700 psi to start setting of PHL packer. 18.8 Continue to pressure up to 3,000 psi to set packer. JA �' 18.9 Pressure up to 3,500 l2si to test tubing for 30 minutes and chart. V i 18.10 Bleed tubing to 2,000 psi. 18.11 Pressure up annulus to 3,500 psi to test casing/packer for 30 minutes and chart. 18.12 Bleed tubing to 0 psi. Pop shear valve from annulus to tubing (2,500 psi differential). 18.13 RILDS and test hanger. LD landing joint. 18.14 Install BPV. Pressure up on 3-1/2" x 7" annulus to 500psi, to test BPV from below. 5 min. 18.15 N/D BOP. 18.16 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 18.17 Circulate diesel freeze protection down 3-1/2" x 7" annulus (Volume should equal capacity of tubing to 2500' + tubing annulus to 2500'). Connect IA to tree and allow diesel freeze protect to "U-tube" into position. Note — this may be done post -rig. 18.18 Pull BPV. Set TWC. Test tree to 250 psi low / 5000 psi high. Pull TWC. Set BPV. 18.19 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.20 Notify AOGCC of SVS testing. Test SVS on horizontal run of tree within 5 days of the start of production. Set low pressure trip below 275 psi Moose Pad header & separator pressure. Page 39 19.0 RDMO 19.1 RDMO Doyon 14 Page 40 Milne Point Unit M-18 SB Producer Drilling Procedure 20.0 Doyon 14 Diverter Schematic 21-V6' 2M R,w- 21 - V4' 2M— D V(W "r 21-114' 2A Spe rSpot 15-34' 3M r 214W 2M DSA Page 41 -16' ra opeftN ".1a VMw `IW Drva Lino Milne Point unit M-18 SB Producer Hil U= Drilling Procedure 20.0 Doyon 14 Diverter Schematic 21-V6' 2M R,w- 21 - V4' 2M— D V(W "r 21-114' 2A Spe rSpot 15-34' 3M r 214W 2M DSA Page 41 -16' ra opeftN ".1a VMw `IW Drva Lino H Hilc U -22r orp 21.0 Doyon 14 BOP Schematic K,II Line1�_ Page 42 Milne Point Unit M-18 SB Producer Drilling Procedure 2-7/8" x 5" VBR Blind Rams x 5M HCR ;hoke Line W Gate Valle 2-7/8" x 5" VBR 22.0 Wellhead Schematic 3�•rV re.. L caeJ er'ri —I IIEry xC1Y.CA,C�ZI— I q-tq3-i¢ Milne Point Unit M-18 SB Producer Drilling Procedure T 1 — 1A1Q111G Yx14 'b 50. BLY il' r �a.m su L. rEl. *or. i4C la '• •�21 ecx: . seaa Lasnrc +i rcp lar. jEII 5 SLIM HDL_ ncscwr,lox y.IRFACc9RELSBLHrr LC' eI. 41i)T !E 7t l; Page 43 nwEe +r Yry ICv .ferslsc wn4 Ilei "lF 71 :ucrl Ic.our .� ownol�ssA� f rt'ry: 1G i _.. ..._ .M7d0uE �10-25-17 ,h1c If L'; IO -25'17 NA Jerre WFp14� [, OJ rl�4p[c � EYE I�'2J"li I C H Hilco .M�rp Milne Point Unit M-18 SB Producer Drilling Procedure 23.0 Days Vs Depth 0 WE 6000 x a 0 8000 a v N v 10000 12000 X60, Page 44 MPU M-18 SB OA Producer Days vs Depth 0 5 10 15 20 25 30 Days K HilemE � 24.0 Formation Tops & Information Milne Point Unit M-18 SB Producer Drilling Procedure MPU M-18 Formations (wp06) MD (ft) TVDss TVD (ft) (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2602 -1761 1820 800.8 8.46 L43 5943 -3039 3097 1362.68 8.46 Schrader Bluff NA 7135 -3488 3547 1560.68 8.46 Schrader Bluff OA 7930 -3636 3694 • 1625.36 8.46 a L -Pad Data Sheet Formation Description (Closest & Most Analogous MPU Pad to Moose Pad) GENERALIZED GEOLOGICAL FORECAST SS TVD FM LITH GEOLOGICAL DESCRIPTION COMMENTS u n•w NOTE: Sao individual Well Program for To— GuNk specific casing design. depths, stns, •t 10 60g weights, grades and connections. Ilncomolideledtmnab mW LmaeM end small pawl __ My MnR.Ilbtae. IF SIGNIFICANT AMOUNTS OF GRAVEL 1,000' io D. ARE ENCOUNTERED WHEN DRILLING THE -410tm SURFACE HOLE, THE VISCOSITY OF THE MUD SYSTEM SHOULD IMMEDIATELY BE RAISED TO 150 SEC TO ENSURE EFFECTIVE HOLE CLEANING. 17W Base permafrost nhrbede of sand. Clays aro elol om with oam Z000. a Ildm Nov dcml. watch Possible .idamcking Mile waaNnymaming 1.413 &L-15. sag.. rota -filfeas No hydrates encountered on L -Pad wells drilled to date. Cominted imor0ad. of aero, cbys aM alitabres Wth DeasbNl .h. of cod. Tram. ar p,I% at./- 3100 It 3,000' hbrval .1 .1. 3100 nun be .d.ky.nd fight (1-41). My nbNad. boatman 3000 and 4500 K C U72'.L A 3657 •tarry Y UGNU: seeds of ccam.ni, u .nf.andewtchar. (A&cDl roam, of: (nom top m bdtom) manm mond fl. as M. alty.hala seas}developed lmarvanlnp slwNs as y+u UGNU pa". Into the Lied M(dceDer). t)gmand SChmdel Bimh Pmmlm.lrydrwrbomlimited luny WSWcomerof Miimd.vvI.De nt Nonhemamai. last day n.tmcf..od.t. I+ta.cl -000' INA) Schrader Bluff Sands: 4,000'lasso. Nd,,,,, comimba tymringcmasnng apwara uedssaew• '40— Schrader Biuff: Possible lost circulation EF) exoWtmomcme.madaMwln Deualmalcoal. zone while drilling long strings and running -170' oew,y My rich stale Imetal43M to 4WD It ugm and Schrader Bluff. Poselbw Mdr.0tom Netted! casing. Recommend deep setting surface (OA) Mum doveloprwnt tar aro Las am rasing for Kuparuk long strings. Also, the D1.1)tosWcornerof mmpNren n.samderelmr.ann fanlwm amaM Schrader Bluff sands are a potential Schrader L -Pad le dotrotm turoaM coot. differential stuck pipe interval If left un -used Bluff. C surface ".IN Dela n.Iwle blow for Kuparuk long strings. Sands: i Sander slot OB seed for loner mach welb. Page 45 25.0 Anticipated Drilling Hazards Milne Point Unit M-18 SB Producer Drilling Procedure 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 not been seen on Moose pad. However, be prepared for them. 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. 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: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. Page 46 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 1-12S 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 M-18 SB Producer HilcoTy Ev 41T Drilling Procedure 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 1-12S 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 N Hilc� 8-1/2" Hole Section: Milne Point Unit M-18 SB Producer Drilling Procedure Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if 1-12S 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 det ' raee ���be developed. z Abnormal Pressures and Temperatures: o e noimal. Abnormal (offset injection) pressure has been seen on M - 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. Reference A/C report in directional plan. w ArT C- (' Page 48 Milne Point Unit M-18 SB Producer Hilcorp Drilling Procedure =75 26.0 Dovon 14 I LW Page 49 27.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit M-18 SB Producer Drilling Procedure 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 50 H Hilcorp Envy fop y 28.0 Doyon 14 Choke Manifold Schematic Milne Point Unit M-18 SB Producer Drilling Procedure Page 51 U Hilcorp 29.0 Milne Point Unit M-18 SB Producer Drilling Procedure Casing Design 11 Hite w Calculation & Casing Design Factors DATE: 4/26/2019 WELL: MPU M-18 DESIGN BY: Joe Engel In Criteria: Hole Size 12-1/4" Mud Density: 9.2 ppg Hole Size 8-1/2" Mud Density: 9.2 ppg Hole Size Mud Density: Drilling Mode MASP: 1257 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1257 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 52 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 6-5/8" Top (MD) 0 8,076 Top (TVD) 0 3,698 Bottom (MD) 6,076 16,721 Bottom (TVD) 3,698 3,960 Length 8,076 8,645 Weight (ppf) 40 20 Grade L-80 L-80 Connection TXP H563 Weight w/o Bouyancy Factor (Ibs) 323,040 • 172,900 Tension at Top of Section (Ibs) 323,040 172,900 Min strength Tension (1000 Ibs) 916 459 Worst Case Safety Factor (Tension) 2.84 , 2.65. Collapse Pressure at bottom (Psi) 1,827 1,956 Collapse Resistance w/o tension (Psi) 3,090 3,470 Worst Case Safety Factor (Collapse) 1.69 1.77• MASP (psi) 1,257 1,257 Minimum Yield (psi) 5,750 1 6,090 Worst case safety factor (Burst) 4.57 1 4.84 Page 52 H Hilcorp �T -� Milne Point Unit M-18 SB Producer Drilling Procedure 30.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 11 8-1/2" Hole Section Hilcorp MPU M-18 Milne Point Unit MD TVD Planned Top: 8076 3698 Planned TD: 16721 3793 Anticipated Formations and Pressures: Formation TVD TVDss Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sandi 40 1627 1 Oil 8.46 0.440 Offset Well Mud Densities well MW ranee Ton (TVD) Bottom fTVD) Date L-50 8.8-9.1 Su rface 4125 2015 L-49 9.0-9.2 Su rface 4196 2015 L-48 8.9-9.2 Su rface 4147 2015 L-47 8.8-9.0 Su rface 4158 2015 L-46 9.0-9.3 Su rface 4177 2015 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-S/8" shoe considering a full column of gas from shoe to surface: 3,698 (ft) x 0.78(psi/ft)= 2884.4 2884(psi)-[0.1(psi/ft)*3698(ft)]= 2515 psi MASP from pore pressure (complete evacuation of wellbore to gas from 3698 (ft) x 0.44(psi/ft)= 1627 psi 1627(psi)-0.1(psi/ft)*3698(ft) 1257 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. Page 53 31.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit M-18 SB Producer Hilco UC,2P Drilling Procedure 31.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit •.+ MPU M-18 Well WPO6 Page 54 U 1,250 2,500 T @mmmmmM==== Feet •�• ,�•'.•, �ytt ADL388235'-Sec. 12 ,r AUL•02550$Y5e°,T' r�� i' i ,' ADL355023 UPARVK RIVER UNR "- ••; >� • fy(' IA t,-: � �' �s;� ` ,/ �\L ♦\ lye- r ♦ I i.y.i PUM-IS-Custcr SHL ••-�'-�:�"+. r'♦ t , `; '•+ � ;;tom au.L ,.'•-'`.' � 1 r , •r'•7. � sec.. id "`" Sr<'1] I' I E3G8• i ' + .sec. t]` \ r 1 , MIYtl •.. 11 � r , / F 1 ,,•` MILNE POINT UNI i • '•` r• i t ' ' ' "- 'D 2P51 B I , A `02551 ` t , r 1 1 r `• r U013NOOBEr \ \fPC Af-15 -Custcr TPH r j^, ; U013N010E t t , 1 ♦Cup 23 � S�' Stt. 19M I' stt.2"u _pec. 153]i r 1 r 1 , / VLY_di LL I•.Yii' Ll .11'C' lam+ � .'�:I��tl, -., .J1 MENT'PAD -- -�-. .mpu V-IS-Custcr BHL , Legend •.__ ,..v_—.����r w, r • MPUMAS-Cuzler_SfLL OMer Surface Hales ,'SeLL) ABL025517• seC'20 .� �Stt 29 '•\ -" pair XMPU M -18 -Custer TPH [BHL? •+-tl.�_���-1♦"--" - - - Glher Nell Pans I " y T MPU wla- Custer BILL Coasefr![USG51:6]kf , ' nci OQI and Gas Ural 8..da •1 + b '. ,I t . Pad F esprim ./ r f Milne Point Unit •.+ MPU M-18 Well WPO6 Page 54 U 1,250 2,500 T @mmmmmM==== Feet Milne Point unit M-18 SB Producer Hilcox Drilling Procedure Enap C®P.^Y 32.0 Surface Plat (As Built) (NAD 27) Page 55 / , PacT GIRD �� 1 NpiE I A9 _I 4G 12 mc.11 -3G SEG 13 T _ 14 4 PAD�a 1 I Y-10 I Y/ ■ I M-11 I i . N -IS IIN .-w 1 23 1 PINE 41E E M-20 ■ I IN Y -IS I M-21 + I VICINITY MAP Nis M-22 M-17 M-18 I I LEGEND M-19 + As -VANED C0N0uC708 II in O0S1N0 C01p1C10N I NO M_o A WAR w caaElHAM u W27, ZM a. x ft0 m MIN0,42 ARE I'V21. 1 CII HOINZONT� cams 6 Nos PAD 3, SURNY: NARpi 1l099RMx 5. DA16�� 6 IIEIFP w NM 00p. NM P4 M -Ox 7. Xflt PpAEPLY mom AS M-1 Mai RNWO N Y-20. GRAPHIC SCALE a 100 20J I00 I PAD I LIN aTti ) MOOSE I FM -200 1L LOCATED WITHIN PROTRACTED SEC. 14, T. 13 N., R. 9 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC SECTION PAD CELLAR BASE NO. COORDINATES COORDINATES POSITION DMS POSITION D.DD OFFSETS ELEVATION BOX EL. FLANGE EL. Y. 6,027,765.62 N. 1,168.00 70'29'12.791" 70.4868864' 4,914' FSL 25.3' N/A N/A N-17 X= 533,633.87 E= 1,635.02 149'43'30.357- 149.7250992' 531' FEL Y= 6,027,765.60 N- 1,167.98 7029'12.793" 70.4868869' 4,915' FSL 25.3' • N/A N/A M-18 X. 533.603.85 E. 1,605.00 149'43'31.241" 149.7253447 561' FEL Y= 6,027,765.63 N= 1,166.02 7029'12.797' 70.4868881' 4,915' FSL 25.5' N/A N/A M-19 X. 533,513.85 E. 1,514.99 149'4333.889 149.7260803' 651' FEL Y= 6,027,089.61 N- 1,292.00 7029'14.006' 70.4872239' 5.038' FSL 25.1' N/A N/A M-21 X. 533,753.82 E. 1,754.98 149'43'26.812' 149.7241144' 441' FEL Y= 61027.889.65 N. 1,292.05 70'29'14.010' 70.4872250- 5,038' FSL 25.1' N/A N/A M-22 X= 533,663.83 E. 1,664.99 149'43'29.459' 149.7248497' 501' FEL w Hilcorp Alaska �I MPU MOOSE PADIN 1B9 b� AS -STAKED CONDUCTORS ->aa WELLS 17,18,19,21,22 1v1 Page 55 Milne Point unit M-18 SB Producer Hilcorp Drilling Procedure � zrp 33.0 Schrader Bluff OA Sand Offset MW vs TVD Chart Schrader Bluff OA Sand Offset MW vs ND I/ mw, PPB 8.S 8.7 8.9 9.1 9.3 9.5 9.7 9.9 10.1 10.3 10.5 0 1 [fill 500 1000 1500 2000 0 2500 3000 3500 4000 4500 Page 56 -MPU L-46 (2015) -MPU L-47 (2015) -MPU L-48 (2015) MPU L-49 (2015) -MPU L-50 (2015) -MPU F-106 (2017) -MPU F-107 (2017) -MPU F-108 (2017) -MPU F-109 (2017) -MPU F-110 (2017) VA H Hilcorp Ur_ Milne Point Unit M-18 SB Producer Drilling Procedure 34.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50 Drill Pipe Configuration Pipe Body OD In: 5.D00 Pipe Body Wall Thickness m. 0.362 Pipe Body Grade S -M DNI Pipe Length Tool Joint SMYS Connection GPDS50 Tod Joint DD 6.625 Tod Joint ID m: 325D Pin Torg 9 Box Tong m: 12 80 % ImpecUon Class Nominal Nominal Weight Designation 19.50 Drill Pipe Approximate Length an; 31.5 SmootrR Height cm, 3732 Rased Tool Joint SMYS n511 120 0=00Upset Type IEU Max Upset OD (DTE) nm 5.125 Friction Factor 11.0 Box OD rvox: Tarp Swc=may mime narvanro Drill Pipe Performance Drill -Pipe Length Rangel Performance of Drill Pipe with Pipe Body at 80 % Insoection Class 100 Connection Performance Tension Only Q 560800 ccmanm--M32,100 467.400 NOR: mn"as ",'...- GPDS50 ( Nde.TO mvpn6e[Onne[Rn Ovemacnul Rnsle.aNWi?11-9i,.COSnlOSI SOOUYJ Oe aGLIbY Nominal Tool Jdnt Tor kxW Strength m m51 71,800 Tod Jd it Tensle Saenath 4 )11.250.000 Elevator Shoulder Information 560840 Pipe Torsional Stenp SmoothEdge Height 58.100 3132 Raised TJlPipeBody Torsional Ratio 7 Box OD enl 6.812 80% Pipe Torsional Sire tone=I 59.3DO Elevator Capadty 6=1 1.638,000 Best Estimates Nominal tsme5fdlrpl (...m cmurpl [k'+S+rcnat) Wit 2329 1.37 0.36 low 0.0085 1.11 0.70 0.72 1.0169 0.0197 0.0172 No's On M10 GYRI WuaISJ3 U8 gallons. aeit r2mM`sinC INY'/O-/eisbpw p3n'mlll lverartt.IMempl Clx:C-+la1Np m0alrxrlsta. 6.625 m3 OD X 3.250 m1 to ) 120,000 oal Tool Joint Dimensions Belalxad OD nn16.435 Sanmltll TpN.IQn aosr un 5.930 PrtmYm Clsss 9n Nranum Tpsl Jtlm oo er 5.93 CbvnlvGaR Ilnl 3132 Rased hm to Men TJ OD for API Premium Class A.,,m.d Fre.Mir Rnm f)uSmMnr W45.219 Nm A 1 - wagonaaxpma=Su�rca erc.ser eorc. npwwrracicr. ane cmlx3slR33 ar r3o.5oms1. NP -Arc lxc] ton 001 Pipe Body Slip Crushing Capacity If -. ra eYrva nuea.C3 e4valtt[�a[Ny'MNM aRMnp rtase.up laipue. Pipe Body CDnliguretion ( 5 m1 OD 0.362 m1 Wall S-135) Pipe Bodv Performance Grant o II Pie Baty Conligumtkin ( 5 rnl OD 0.362 m) Wall S-135) Nde: Nmi5rp16YR1 ca[Ylitrd al � yY RB'N pn 1PI. f Page 57 Nominal 80 a/ Inspection Class API Premnan Class Pipe Tensile strength em1712100 560800 560840 Pipe Torsional Stenp 74,160 58.100 58.1W TJlPipeBody Torsional Ratio 0.97 1.24 124 80% Pipe Torsional Sire tone=I 59.3DO 46.500 46.500 Burst .,j 17,105 15,638 15638 Collapse rmn 15.672 10.029 10.029 Pipe OD Ol 5.000 4.855 4.855 Wall Thickness na! 0.362 0.290 0.290 Nominal Pipe ID ea 4276 4.276 4276 Cross Sectional Area of Pipe Body mvl 5275 4.154 4.154 Cross sectional Area of OD m•n 19.635 18.514 16.514 Cross Sectional Area of ID oe•m 14.360 114.360 14.360 section Modulus o,A3r 5.708 14.476 4A76 Polar Section Modulus M-31111.415 18.953 8.953 Nde: Nmi5rp16YR1 ca[Ylitrd al � yY RB'N pn 1PI. f Page 57 H Hilcox E.v ® Milne Point Unit M-18 SB Producer Drilling Procedure 500204050016200 Weatherford 5" 19.50 Ib/ft S-135 w/ NC 50 6-5/8" OD x 3-1/4" ID Tool Joint DRILL PIPE SPECIFICATIONS Grade S-135 Connection NC 50 Interchangeable With 5' XH & 4-12' IF Upset Type IEU Nominal Weight per Foot 1 19.50 lbs Adjusted Weight With Tool Joint per Foot 1 23.08 lbs TOOL JOINT DATA Outside Diameter 6-518' Inside Diameter 3-114' API Drift 3-1/8' Rabbit OD. Suggested 3-1/16" Minimum Make-up Torque 25.900 ft -lbs Maximum Recommend Make-up Torque 26,800 ft -lbs Torsional Yield Strength 51.700 ft -lbs Tensile Strength 1.269,000 lbs TUBE DATA New Premium Outside Diameter 5.000' 4.855' Inside Diameter 4.276" 4.276' Wall Thickness 0.362' 0.290' Cross Sectional Area 5.275 sq in 4.154 sq in Maximum Hook Load/rensile Strength 712.000 lbs 560.800 lbs Slip Crushing / Slip Type (SDXL) 572,100 lbs 453,500 lbs Burst Pressure 17,100 psi 16.100 psi Collapse Pressure 15.700 psi 10.000 psi Torsional Yield Stren th 74.100 ft -lbs 58.100 ft -lbs Capacity W/ Tool Joint 0.726 US ayft 0.726 US al/ft Displacement WI Tool Joint 0.353 US aVft 0.322 US aalM Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss. damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 58 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-18 MPU M-18 -Custer Plan: MPU M-18 wp06 Standard Proposal Report 24 April, 2019 HALLIBURTON Sperry Drilling Services Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPUM-18 Wellbore: MPUM-I8-Coate Design: MPUM-18 wp06 MAW9URTON ® ool = zas2 HiAnry Abode. LLC Glmlal'a+MMod Mlnlmum OurvaWn Eno, Sytam' ISCWJA Soon n MCMcd: Closest AppoaN JO Ener Surfea: Pa]al Curvy Warning Modem Enor RaOa 750 c 1500 0 2250 i F 3000 CASINO DETAILS REFERENCE INWRIM11ON WELL DLTNIS: M- Mod M18 Np Np6S MD 3uxa Name CoaEN»INE)Rebesu:. a WVunB. Tw wn ileo 3685.fi0 364000 8076.08 8 -SR 9518'x 121N' m11R'1xl Wte+erm'YFV +BRe4nganM RNB®SBYueB NI�4 • ... Eeetln Le od� 379360 373500 +6]2152 6 -SR 6518'812' um Rpm Mkrenre: WUMt PmangenM BZB495Bm:1 BBxTMceo sv�i.asIn n i tiwmM Yeuze:..- done. Start Dir 30/100': 330'MD, 330T1) �O O 10-- Stan Dir 4011W: 550' MD, 549.STTVD ^t? �1< to O -- - Start Dir 5.1100': 750' MD, 745.94' D of 0600 IQOD End Dir :1805.50' M0,151535' WD 0 ^y g0. Ap 6 O 16. e4 00 p oma, m c 9515'x12114`- 0 750 1500 22W 3000 3750 M-18 Heel wp03a $ c Dela: 2018a2-ssTDOmm Valkrs ated:Vea Verson: Depth From Ceoai To Barveye'lon Tool 3J.70 8076.08 Lou M -16x906 3 MAD,IFRD+MBaSa ol -�) ^ -rr lFr^-rte 5250 6000 6750 7500 USO 9000 9750 Vertical Section at 125.27' (1500 nftM) on l-' 500 11250 12000 12750 6 5e, 812 - MPU M-10 WMW 16722 ,- M-18 wpO5 Toe Ad NO -N/-S +EI -W DIB TF- vs At jet Anmtelion 1 33.70 ,a D.00 33.70 0.00 0.00 coo 0.00 D00 2 33000 0.00 000 330.00 000 000 0.00 000 000 and DI, 3-11 CU': 330' MD, 330'IVD 3 550.00 660 16000 5 9,51 -11.09 4.33 3.00 160.00 10.40 Stan Our 4.1100': 550' MO, 54951 T]D 4750.00 14.60 160.00 745.94 -46H 16.90 4.00 0.00 40.61 Sla, Dir 5°/100': 750' MD, 745.94T]D 5 180550 57.32 164.61 1515.35 -686.92 20547 500 534 584.18 End Dir :1805.58' MD,1515.3N 6 672897 6732 164.61 3413.35 -5066.82 1410.96 0.00 coo 4077.70 SUrt DiN°llffl' 67naTMD,341335'ND 7 T]76 OB 8500 125.27 3672.45 -5869.80 1991.09 4.00 -71.07 5015 00 End On, :7]7608' MD, 3672.45' ND 0 807600 8500 125.27 369860 -604236 2235M 000 000 5313.86 M-18 Heel Wp03 Sled Dir 4'1100 807800' M0, 3690.8 90186.04 09.40 1253] 3703.97 -6105.75 2324.74 4.00 0.00 5423.66 End DIr:81W.04'MD, 3703ATTV0 10 16]21.52 89AD 125.27 3793,60 -11033.79 9293.31 0,00 0.00 13950.68 M-10.05 Ted Total Depth : 16721.52' MD, 37936' TV➢ CASINO DETAILS REFERENCE INWRIM11ON WELL DLTNIS: M- Mod M18 Np Np6S MD 3uxa Name CoaEN»INE)Rebesu:. a WVunB. Tw wn ileo 3685.fi0 364000 8076.08 8 -SR 9518'x 121N' m11R'1xl Wte+erm'YFV +BRe4nganM RNB®SBYueB NI�4 • ... Eeetln Le od� 379360 373500 +6]2152 6 -SR 6518'812' um Rpm Mkrenre: WUMt PmangenM BZB495Bm:1 BBxTMceo sv�i.asIn n i tiwmM Yeuze:..- done. Start Dir 30/100': 330'MD, 330T1) �O O 10-- Stan Dir 4011W: 550' MD, 549.STTVD ^t? �1< to O -- - Start Dir 5.1100': 750' MD, 745.94' D of 0600 IQOD End Dir :1805.50' M0,151535' WD 0 ^y g0. Ap 6 O 16. e4 00 p oma, m c 9515'x12114`- 0 750 1500 22W 3000 3750 M-18 Heel wp03a $ c Dela: 2018a2-ssTDOmm Valkrs ated:Vea Verson: Depth From Ceoai To Barveye'lon Tool 3J.70 8076.08 Lou M -16x906 3 MAD,IFRD+MBaSa ol -�) ^ -rr lFr^-rte 5250 6000 6750 7500 USO 9000 9750 Vertical Section at 125.27' (1500 nftM) on l-' 500 11250 12000 12750 6 5e, 812 - MPU M-10 WMW 16722 ,- M-18 wpO5 Toe I SIM Di=4'IIOU':6R5.9P �. N13.3)'IYD )250 t`� L20ir Mn. l6Ra5'Nn W:m]6.08' Ma,36996'Nn M�Itl N¢I x#i) 6518"fl IR'-__ .a W05 T¢ MPUM�18 nnOt 0 1000 2000 30M 4000 5000 60M 7000 8000 9000 10000 11000 Wfw(-)I d+) (2000 usWin) 15000 16000 17000 18000 19000 I CASING news Project: Milne Point rw TVDSSs m Mo Name Site: M Pt Moose Pad 3698.6) )64000 e" 80)606 S 9.518 93re". li lla•• Well: Plan: MPU M48 n,6o 9> nss.aa 16N_Lsa 6sre 6sla•a vz" Wellbore: MPUM-18-Custer Plan: MPU M-18 wp06 $un Cv I'.I W':llp M0, l)VNn "- - sw u. rnmsssnlno, s49svrw HALLIBURTON weu oars: P1.:rau M.le Sml nl, PAW: 75& m 745.94'rw Win, Inawe= wnywle -- ENni, :IBfi Sfl'AN,I515ISTW o!w noo w ias•%o 5))6U1,85 70.2WISN25K 1118. REFERENCE INFORM4TION 1]50 Wnd=aie Mal aelen�: wee PWe IIDUMI& Trve NM, 1 WNW fM1Dl Nele,eive'. MPNM�18 RYm P4nro5 Fl(B ®StlfO¢4 A� v PNa®SBWUM i'2{NN k�iAaln IMYwS: Wmmulm EweuimroYnreO SIM Di=4'IIOU':6R5.9P �. N13.3)'IYD )250 t`� L20ir Mn. l6Ra5'Nn W:m]6.08' Ma,36996'Nn M�Itl N¢I x#i) 6518"fl IR'-__ .a W05 T¢ MPUM�18 nnOt 0 1000 2000 30M 4000 5000 60M 7000 8000 9000 10000 11000 Wfw(-)I d+) (2000 usWin) 15000 16000 17000 18000 19000 HALLIBURTON Database: NORTH US + CANADA Company: Hiloorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-18 Wellbore: MPU M-18 - Custer Design: MPU M-18 wp06 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU M-18 TVD Reference: MPU M-18 Prelim Planned IRKS @ 58.60usft MD Reference: MPU M-18 Prelim Planned RKB @ 58.60usft North Reference: True Survey Calculation Method: Minimum Curvature 'roject Milne Point, ACT, MILNE POINT lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ieo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt Moose Pad Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan: MPU M-18 Well Position +NIS 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Wellbore Magnetics Design Audit Notes: Version: Vertical Section: MPU M -18 -Custer Model Name BGGM2018 MPU M-18 wp06 Northing: 6,027,877.65usft Latitude: 70° 29' 13.9052 N Easting: 533,363.92usft Longitude: 149° 43'38.2855 W Slot Radius: 13-3116" Grid Convergence: 0.26 ° Northing: 6,027,765.60 usft . Latitude: 70' 29' 12.7925 N Easting: 533,603.85 usft . Longitude: 149° 43'31.2407 W Wellhead Elevation: usft Ground Level: 24.90 usft Sample Date Declination Dip Angle Field Strength (") (°) (nT) 4/30/2019 16.66 80.96 57,427.88344269 Phase: PLAN Tie On Depth: 33.70 Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (°) 33.70 0.00 0.00 125.27 Measured Dogleg Build Vertical TVD Depth Rate Inclination Azimuth Depth System (usft) 0.00 (°i (°) (usft) usft 33.70 0.00 0.00 0.00 33.70 -24.90 330.00 16.90 0.00 0.00 330.00 271.40 550.00 4.99 6.60 160.00 549.51 490.91 750.00 1,991.09 14.60 160.00 745.94 687.34 1,805.58 0.00 67.32 164.61 1,515.35 1,456.75 6,728.97 9,293.31 67.32 164.61 3,413.35 3,354.75 7,776.08 85.00 125.27 3,672.45 3,613.85 8,076.08 85.00 125.27 3,698.60 3,640.00 8,186.04 89.40 125.27 3,703.97 3,645.37 16,721.52 89.40 125.27 3,793.60 3,735.00 +N/S (usft) 0.00 0.00 -11.89 -46.44 -686.92 -5,066.82 -5,869.80 -6,042.36 -6,105.75 -11,033.79 Tool Face 0.00 0.00 160.00 0.00 5.34 0.00 -71.07 0.00 0.00 0.00 41242019 11 55:08AM Page 2 COMPASS 5000.15 Build 91 Dogleg Build Turn +EI -W Rate Rate Rate (usft) (°/100usft) (°/t00usft) (°1100usft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.33 3.00 3.00 0.00 16.90 4.00 4.00 0.00 205.17 5.00 4.99 0.44 1,410.96 0.00 0.00 0.00 1,991.09 4.00 1.69 -3.76 2,235.09 0.00 0.00 0.00 2,324.74 4.00 4.00 0.00 9,293.31 0.00 0.00 0.00 Tool Face 0.00 0.00 160.00 0.00 5.34 0.00 -71.07 0.00 0.00 0.00 41242019 11 55:08AM Page 2 COMPASS 5000.15 Build 91 Halliburton HALLIBURTON Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: NORTH US + CANADA Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-18 MPU M -18 -Custer MPU M-18 wp06 Local Coordinate Reference: Well Plan: MPU M-18 TVD Reference: MPU M-18 Prelim Planned RKB @ 58.60usft MD Reference: MPU M-18 Prelim Planned RKB @ 58.60usft North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -24.90 33.70 0.00 0.00 33.70 -24.90 0.00 0.00 6,027,765.60 533,603.85 0.00 0.00 100.00 0.00 0.00 100.00 41.40 0.00 0.00 6,027,765.60 533,603.85 0.00 0.00 200.00 0.00 0.00 200.00 141.40 0.00 0.00 6,027,765.60 533,603.85 0.00 0.00 300.00 0.00 0.00 300.00 241.40 0.00 0.00 6,027,765.60 533,603.85 0.00 0.00 330.00 0.00 0.00 330.00 271.40 0.00 0.00 6,027,765.60 533,603.85 0.00 0.00 Start Dir 3°1100' : 330' MD, 330'TVD 400.00 2.10 160.00 399.98 341.38 -1.21 0.44 6,027,764.40 533,604.29 3.00 1.05 500.00 5.10 160.00 499.78 441.18 -7.11 2.59 6,027,758.51 533,606.47 3.00 6.21 550.00 6.60 160.00 549.51 490.91 -11.89 4.33 6,027,753.73 533,608.23 3.00 10.40 Start Dir 401100' : 550' MD, 549.51'TVD 600.00 8.60 160.00 599.07 540.47 -18.11 6.59 6,027,747.52 533,610.52 4.00 15.84 700.00 12.60 160.00 697.35 638.75 -35.39 12.88 6,027,730.27 533,616.89 4.00 30.95 750.00 14.60 160.00 745.94 687.34 -46.44 16.90 6,027,719.24 533,620.96 4.00 40.61 Start Dir 5°/100' : 750' MD, 745.94'7VD 800.00 17.09 160.79 794.04 735.44 -59.30 21.48 6,027,706.40 533,625.59 5.00 51.77 900.00 22.08 161.85 888.22 829.62 -91.05 32.17 6,027,674.70 533,636.43 5.00 78.84 1,000.00 27.07 162.54 979.14 920.54 -130.64 44.86 6,027,635.17 533,649.29 5.00 112.06 1,100.00 32.06 163.02 1,066.09 1,007.49 -177.77 59.45 6,027,588.12 533,664.09 5.00 151.18 1,200.00 37.06 163.39 1,148.41 1,089.81 -232.06 75.82 6,027,533.91 533,680.71 5.00 195.90 1,300.00 42.06 163.68 1,225.49 1,166.89 -293.12 93.86 6,027,472.94 533,699.03 5.00 245.89 1,400.00 47.05 163.92 1.296.72 1,238.12 -360.47 113.42 6,027,405.68 533,718.89 5.00 300.75 1,500.00 52.05 164.12 1,361.57 1,302.97 -433.61 134.36 6,027,332.64 533,740.16 5.00 360.08 1,600.00 57.05 164.30 1,419.55 1,360.95 -511.98 156.52 6,027,254.39 533,762.67 5.00 423.42 1,700.00 62.05 164.46 1,470.22 1,411.62 -594.97 179.73 6,027,171.51 533,786.25 5.00 490.29 1,805.58 67.32 164.61 1,515.35 1,456.75 -686.92 205.17 6,027,079.68 533,812.10 5.00 564.16 End Dir : 1805.58' MD, 1515.35' TVD 1,900.00 67.32 164.61 1,551.75 1,493.15 -770.92 228.29 6,026,995.79 533,835.60 0.00 631.54 2,000.00 67.32 164.61 1,590.30 1,531.70 -859.88 252.79 6,026,906.95 533,860.49 0.00 702.91 2,100.00 67.32 164.61 1,628.85 1,570.25 -948.84 277.28 6,026,818.11 533,885.38 0.00 774.27 2,200.00 67.32 164.61 1,667.40 1,608.80 -1,037.80 301.77 6,026,729.27 533,910.27 0.00 845.63 2,300.00 67.32 164.61 1,705.95 1,647.35 -1,126.77 326.26 6,026,640.43 533,935.16 0.00 917.00 2,400.00 67.32 164.61 11744.50 1,685.90 -1,215.73 350.75 6,026,551.59 533,960.05 0.00 988.36 2,500.00 67.32 164.61 1,783.05 1,724.45 -1,304.69 375.24 6,026,462.75 533,984.94 0.00 1,059.73 2,600.00 67.32 164.61 1,821.60 1,763.00 -1,393.65 399.73 6,026,373.91 534,009.83 0.00 1,131.09 2,700.00 67.32 164.61 1,860.15 1,801.55 -1,482.61 424.22 6,026,285.07 534,034.72 0.00 1,202.46 2,800.00 67.32 164.61 1,898.70 1,840.10 -1,571.57 448.71 6,026,196.23 534,059.62 0.00 1,273.82 2,900.00 67.32 164.61 1,937.25 1,878.65 -1,660.53 473.20 6,026,107.39 534,084.51 0.00 1,345.18 3,000.00 67.32 164.61 1,975.80 1,917.20 -1,749.49 497.70 6,026,018.55 534,109.40 0.00 1,416.55 3,100.00 67.32 164.61 2,014.35 1,955.75 -1,838.45 522.19 6,025,929.71 534,134.29 0.00 1,487.91 3,200.00 67.32 164.61 2,052.90 1,994.30 -1,927.41 546.68 6,025,840.87 534,159.18 0.00 1,559.28 3,300.00 67.32 164.61 2,091.46 2,032.86 -2,016.37 571.17 6,025,752.03 534,184.07 0.00 1,630.64 3,400.00 67.32 164.61 2,130.01 2,071.41 -2,105.33 595.66 6,025,663.19 534,208.96 0.00 1,702.00 3,500.00 67.32 164.61 2,168.56 2,109.96 -2,194.30 620.15 6,025,574.35 534,233.85 0.00 1,773.37 3,600.00 67.32 164.61 2,207.11 2,148.51 -2,283.26 644.64 6,025,485.50 534,258.74 0.00 1,844.73 3,700.00 67.32 164.61 2,245.66 2,187.06 -2,372.22 669.13 6,025,396.66 534,283.63 0.00 1,916.10 412412019 11:55:08AM Page 3 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-18 Wellbore: MPU M -18 -Custer Design: MPU M-18 wp06 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft 3,800.00 67.32 164.61 2,284.21 2,225.61 3,900.00 67.32 164.61 2,322.76 2,264.1E 4,000.00 67.32 164.61 2,361.31 2,302.71 4,100.00 67.32 164.61. 2,399.86 2,341.2E 4,200.00 67.32 164.61 2,438.41 2,379.81 4,300.00 67.32 164.61 2,476.96 2,418.3E 4,400.00 67.32 164.61 2,515.51 2,456.91 4,500.00 67.32 164.61 2,554.06 2,495.46 4,600.00 67.32 164.61 2,592.61 2,534.01 4,700.00 67.32 164.61 2,631.16 2,572.56 4,800.00 67.32 164.61 2,669.72 2,611.12 4,900.00 67.32 164.61 2,708.27 2,649.67 5,000.00 67.32 164.61 2,746.82 2,688.22 5,100.00 67.32 164.61 2,785.37 2,726.77 5,200.00 67.32 164.61 2,823.92 2,765.32 5,300.00 67.32 164.61 2,862.47 2,803.87 5,400.00 67.32 164.61 2,901.02 2,842.42 5,500.00 67.32 164.61 2,939.57 2,880.97 5,600.00 67.32 164.61 2,978.12 2,919.52 5,700.00 67.32 164.61 3,016.67 2,958.07 5,800.00 67.32 164.61 3,055.22 2,996.62 5,900.00 67.32 164.61 3,093.77 3,035.17 6,000.00 67.32 164.61 3,132.32 3,073.72 6,100.00 67.32 164.61 3,170.87 3,112.27 6,200.00 67.32 164.61 3,209.42 3,150.82 6,300.00 67.32 164.61 3,247.98 3,189.38 6,400.00 67.32 164.61 3,286.53 3,227.93 6,500.00 67.32 164.61 3,325.08 3,266.48 6,600.00 67.32 164.61 3,363.63 3,305.03 6,700.00 67.32 164.61 3,402.18 3,343.58 6,728.97 67.32 164.61 3,413.35 3,354.75 Start Dir 4°/100' : 6728.97' MD, 3413.35TVD 6,800.00 68.27 161.71 3,440.19 3,381.59 6,900.00 69.69 157.71 3,476.07 3,417.47 7,000.00 71.20 153.77 3,509.56 3,450.96 7,100.00 72.78 149.91 3,540.48 3,481.88 7,200.00 74.44 146.12 3,568.70 3,510.10 7,300.00 76.17 142.39 3,594.07 3,535.47 7,400.00 77.95 138.71 3,616.48 3,557.88 7,500.00 79.77 135.09 3,635.80 3,577.20 7,600.00 81.64 131.50 3,651.96 3,593.36 7,700.00 83.54 127.95 3,664.86 3,606.26 7,776.08 85.00 125.27 3,672.45 3,613.85 End Dir : 7776.08' MD, 3672.45' TVD 7,800.00 85.00 125.27 3,674.54 3,615.94 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU M-18 TVD Reference: MPU M-18 Prelim Planned RKB @ 58.60usft MD Reference: MPU M-18 Prelim Planned IRKS @ 58.60usft North Reference: True Survey Calculation Method: Minimum Curvature -5,883.56 2,010.54 6,021,891.77 535,640.76 0.00 5,038.83 4242019 11:55:08AM Page 4 COMPASS 5000.15 Build 91 Map Map +N/ -S +El -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 2,225.61 -2,461.18 693.62 6,025,307.82 534,308.52 0.00 1,987.46 -2,550.14 718.11 6,025,218.98 534,333.41 0.00 2,058.82 -2,639.10 742.61 6,025,130.14 534,358.30 0.00 2,130.19 -2,728.06 767.10 6,025,041.30 534,383.19 0.00 2,201.55 -2,817.02 791.59 6,024,952.46 534,408.08 0.00 2,272.92 -2,905.98 816.08 6,024,863.62 534,432.97 0.00 2,344.28 -2,994.94 840.57 6,024,774.78 534,457.86 0.00 2,415.65 -3,083.90 865.06 6,024,685.94 534,482.75 0.00 2,487.01 -3,172.86 889.55 6,024,597.10 534,507.64 0.00 2,558.37 -3,261.83 914.04 6,024,508.26 534,532.53 0.00 2,629.74 -3,350.79 938.53 6,024,419.42 534,557.42 0.00 2,701.10 -3,439.75 963.02 6,024,330.58 534,582.31 0.00 2,772.47 -3,528.71 987.52 6,024,241.74 534,607.20 0.00 2,843.83 -3,617.67 1,012.01 6,024,152.90 534,632.09 0.00 2,915.19 -3,706.63 1,036.50 6,024,064.06 534,656.98 0.00 2,986.56 -3,795.59 1,060.99 6,023,975.22 534,681.87 0.00 3,057.92 -3,884.55 1,085.48 6,023,886.38 534,706.76 0.00 3,129.29 -3,973.51 1,109.97 6,023,797.53 534,731.65 0.00 3,200.65 -4,062.47 1,134.46 6,023,708.69 534,756.54 0.00 3,272.02 4,151.43 1,158.95 6,023,619.85 534,781.43 0.00 3,343.38 4,240.40 1,183.44 6,023,531.01 534,806.32 0.00 3,414.74 -4,329.36 1,207.93 6,023,442.17 534,831.21 0.00 3,486.11 -4,418.32 1,232.43 6,023,353.33 534,856.10 0.00 3,557.47 4,507.28 1,256.92 6,023,264.49 534,880.99 0.00 3,628.84 -4,596.24 1,281.41 6,023,175.65 534,905.88 0.00 3,700.20 -4,685.20 1,305.90 6,023,086.81 534,930.77 0.00 3,771.56 -4,774.16 1,330.39 6,022,997.97 534,955.66 0.00 3,842.93 -4,863.12 1,354.88 6,022,909.13 534,980.55 0.00 3,914.29 -4,952.08 1,379.37 6,022,820.29 535,005.44 0.00 3,985.66 -5,041.04 1,403.86 6,022,731.45 535,030.34 0.00 4,057.02 -5,066.82 1,410.96 6,022,705.71 535,037.55 0.00 4,077.69 -5,129.75 1,430.01 6,022,642.87 535,056.88 4.00 4,129.59 -5,217.27 1,462.38 6,022,555.50 535,089.65 4.00 4,206.56 -5,303.15 1,501.10 6,022,469.81 535,128.75 4.00 4,287.76 -5,386.97 1,545.98 6,022,386.20 535,174.00 4.00 4,372.80 -5,468.32 1,596.79 6,022,305.09 535,225.17 4.00 4,461.26 -5,546.80 1,653.30 6,022,226.87 535,282.03 4.00 4,552.71 -5,622.04 1,715.22 6,022,151.93 535,344.28 4.00 4,646.71 5,693.65 1,782.25 6,022,080.62 535,411.63 4.00 4,742.79 -5,761.31 1,854.07 6,022,013.30 535,483.75 4.00 4,840.49 -5,824.66 1,930.33 6,021,950.29 535,560.28 4.00 4,939.33 -5,869.80 1,991.09 6,021,905.43 535,621.24 4.00 5,015.00 -5,883.56 2,010.54 6,021,891.77 535,640.76 0.00 5,038.83 4242019 11:55:08AM Page 4 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-18 Company: Hilcorp Alaska, LLC TVD Reference: MPU M-18 Prelim Planned RKB @ 58.60usft Project: Wine Point MD Reference; MPU M-18 Prelim Planned RKB @ 58.60usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-18 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-18 -Custer Design: MPU M-18 wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (0) (usft) usft (usft) (usft) (usft) (usft) 3,624.65 7,900.00 85.00 125.27 3,683.25 3,624.65 -5,941.08 2,091.88 6,021,834.62 535,722.34 0.00 5,138.45 8,000.00 85.00 125.27 3,691.97 3,633.37 -5,998.60 2,173.22 6,021,777.47 535,803.93 0.00 5,238.07 8,076.08 85.00 125.27 3,698.60 3,640.00 -6,042.36 2,235.10 6,021,734.00 535,866.00 0.00 5,313.86 Start Dir 40/100': 8076.08' MD, 3698.6'TVD - 9 518" x 12 114" 8,100.00 85.96 125.27 3,700.49 3,641.89 -6,056.13 2,254.57 6,021,720.32 535,885.53 4.00 5,337.71 8,186.04 89.40 125.27 3,703.97 3,645.37 -6,105.76 2,324.75 6,021,671.01 535,955.93 4.00 5,423.66 End Dir : 8186.04' MD, 3703.97' TVD 8,200.00 89.40 125.27 3,704.12 3,645.52 -6,113.82 2,336.14 6,021,663.00 535,967.36 0.00 5,437.62 8,300.00 89.40 125.27 3,705.17 3,646.57 -6,171.55 2,417.79 6,021,605.64 536,049.26 0.00 5,537.62 8,400.00 89.40 125.27 3,706.22 3,647.62 -6,229.29 2,499.43 6,021,548.28 536,131.15 0.00 5,637.61 8,500.00 89.40 125.27 3,707.27 3,648.67 -6,287.02 2,581.07 6,021,490.92 536,213.04 0.00 5,737.61 8,600.00 89.40 125.27 3,708.32 3,649.72 -6,344.76 2,662.71 6,021,433.56 536,294.94 0.00 5,837.60 8,700.00 89.40 125.27 3,709.37 3,650.77 -6,402.50 2,744.36 6,021,376.20 536,376.83 0.00 5,937.60 8,800.00 89.40 125.27 3,710.42 3,651.82 -6,460.23 2,826.00 6,021,318.84 536,458.73 0.00 6,037.59 8,900.00 89.40 125.27 3,711.47 3,652.87 -6,517.97 2,907.64 6,021,261.48 536,540.62 0.00 6,137.59 9,000.00 89,40 125.27 3,712.52 3,653.92 -6,575.70 2,989.28 6,021,204.12 536,622.52 0.00 6,237.58 9,100.00 89.40 125.27 3,713.57 3,654.97 -6,633.44 3,070.93 6,021,146.76 536,704.41 0.00 6,337.57 9,200.00 89.40 125.27 3,714.62 3,656.02 -6,691.18 3,152.57 6,021,089.40 536,786.30 0.00 6,437.57 9,300.00 89.40 125.27 3,715.67 3,657.07 -6,748.91 3,234.21 6,021,032.04 536,868.20 0.00 6,537.56 9,400.00 89.40 125.27 3,716.72 3,658.12 -6,806.65 3,315.85 6,020,974.68 536,950.09 0.00 6,637.56 9,500.00 89.40 125.27 3,717.77 3,659.17 -6,864.38 3,397.49 6,020,917.31 537,031.99 0.00 6,737.55 9,600.00 89.40 125.27 3,718.82 3,660.22 -6,922.12 3,479.14 6,020,859.95 537,113.88 0.00 6,837.55 9,700.00 89.40 125.27 3,719.87 3,661.27 -6,979.85 3,560.78 6,020,802.59 537,195.78 0.00 6,937.54 9,800.00 89.40 125.27 3,720.92 3,662.32 -7,037.59 3,642.42 6,020,745.23 537,277.67 0.00 7,037.54 9,900.00 89.40 125.27 3,721.97 3,663.37 -7,095.33 3,724.06 6,020,687.87 537,359.56 0.00 7,137.53 10,000.00 89.40 125.27 3,723.02 3,664.42 -7,153.06 3,805.71 6,020,630.51 537,441.46 0.00 7,237.52 10,100.00 89.40 125.27 3,724.07 3,665.47 -7,210.80 3,887.35 6,020,573.15 537,523.35 0.00 7,337.52 10,200.00 89.40 125.27 3,725.12 3,666.52 -7,268.53 3,968.99 6,020,515.79 537,605.25 0.00 7,437.51 10,300.00 89.40 125.27 3,726.17 3,667.57 -7,326.27 4,050.63 6,020,458.43 537,687.14 0.00 7,537.51 10,400.00 89.40 125.27 3,727.22 3,668.62 -7,384.01 4,132.28 6,020,401.07 537,769.04 0.00 7,637.50 10,500.00 89.40 125.27 3,728.27 3,669.67 -7,441.74 4,213.92 6,020,343.71 537,850.93 0.00 7,737.50 10,600.00 89.40 125.27 3,729.32 3,670.72 -7,499.48 4,295.56 6,020,286.35 537,932.82 0.00 7,837.49 10,700.00 89.40 125.27 3,730.37 3,671.77 -7,557.21 4,377.20 6,020,228.99 538,014.72 0.00 7,937.49 10,800.00 89.40 125.27 3,731.42 3,672.82 -7,614.95 4,458.84 6,020,171.63 538,096.61 0.00 8,037.48 10,900.00 89.40 125.27 3,732.47 3,673.87 -7,672.68 4,540.49 6,020,114.27 538,178.51 0.00 8,137.48 11,000.00 89.40 125.27 3,733.52 3,674.92 -7,730.42 4,622.13 6,020,056.90 538,260.40 0.00 8,237.47 11,100.00 89.40 125.27 3,734.57 3,675.97 -7,788.16 4,703.77 6,019,999.54 538,342.30 0.00 8,337.46 11,200.00 89.40 125.27 3,735.62 3,677.02 -7,845.89 4,785.41 6,019,942.18 538,424.19 0.00 8,437.46 11,300.00 89.40 125.27 3,736.67 3,678.07 -7,903.63 4,867.06 6,019,884.82 538,506.08 0.00 8,537.45 11,400.00 89.40 125.27 3,737.72 3,679.12 -7,961.36 4,948.70 6,019,827.46 538,587.98 0.00 8,637.45 11,500.00 89.40 125.27 3,738.77 3,680.17 -8,019.10 5,030.34 6,019,770.10 538,669.87 0.00 8,737.44 11,600.00 89.40 125.27 3,739.82 3,681.22 -8,076.84 5,111.98 6,019,712.74 538,751.77 0.00 8,837.44 11,700.00 89.40 125.27 3,740.87 3,682.27 -8,134.57 5,193.63 6,019,655.38 538,833.66 0.00 8,937.43 11,800.00 89.40 125.27 3,741.92 3,683.32 -8,192.31 5,275.27 6,019,598.02 538,915.56 0.00 9,037.43 11,900.00 89.40 125.27 3,742.97 3,684.37 -8,250.04 5,356.91 6,019,540.66 538,997.45 0.00 9,137.42 4242019 11:55:08AM Page 5 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-18 Company: Hilcorp Alaska, LLC TVD Reference: MPU M-18 Prelim Planned RKB @ 58.60usfl Project: Milne Point MO Reference: MPU M-18 Prelim Planned RKB @ 58.60usft Site: M Pt Moose Pad North Reference: True Well; Plan: MPU M-18 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-18 - Custer Design: MPU M-18 WPO6 Planned survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (0) (1) (usft) usft (usft) (usft) (usft) (usft) 3,685.42 12,000.00 89.40 125.27 3,744.02 3,685.42 -8,307.78 5,438.55 6,019,483.30 539,079.34 0.00 9,237.41 12,100.00 89.40 125.27 3,745.07 3,686.47 -8,365.51 5,520.20 6,019,425.94 539,161.24 0.00 9,337.41 12,200.00 89.40 125.27 3,746.12 3,687.52 -8,423.25 5,601.84 6,019,368.58 539,243.13 0.00 9,437.40 12,300.00 89.40 125.27 3,747.17 3,688.57 -8,480.99 5,683.48 6,019,311.22 539,325.03 0.00 9,537.40 12,400.00 89.40 125.27 3,748.22 3,689.62 -8,538.72 5,765.12 6,019,253.85 539,406.92 0.00 9,637.39 12,500.00 89.40 125.27 3,749.27 3,690.67 -8,596.46 5,846.76 6,019,196.49 539,488.82 0.00 9,737.39 12,600.00 89.40 125.27 3,750.32 3,691.72 -8,654.19 5,928.41 6,019,139.13 539,570.71 0.00 9,837.38 12,700.00 89.40 125.27 3,751.37 3,692.77 -8,711.93 6,010.05 6,019,081.77 539,652.60 0.00 9,937.38 12,800.00 89.40 125.27 3,752.42 3,693.82 -8,769.67 6,091.69 6,019,024.41 539,734.50 0.00 10,037.37 12,900.00 89.40 125.27 3,753.47 3,694.87 -8,827.40 6,173.33 6,018,967.05 539,816.39 0.00 10,137.36 13,000.00 89.40 125.27 3,754.52 3,695.92 -8,885.14 6,254.98 6,018,909.69 539,89829 0.00 10,237.36 13,100.00 89.40 125.27 3,755.57 3,696.97 -8,942.87 6,336.62 6,018,852.33 539,980.18 0.00 10,337.35 13,200.00 89.40 125.27 3,756.62 3,698.02 -9,000.61 6,418.26 6,018,794.97 540,062.08 0.00 10,437.35 13,300.00 89.40 125.27 3,757.67 3,699.07 -9,058.34 6,499.90 6,018,737.61 540,143.97 0.00 10,537.34 13,400.00 89.40 125.27 3,758.72 3,700.12 -9,116.08 6,581.55 6,018,680.25 540,225.86 0.00 10,637.34 13,500.00 89.40 125.27 3,759.77 3,701.17 -9,173.82 6,663.19 6,018,622.89 540,307.76 0.00 10,737.33 13,600.00 89.40 125.27 3,760.82 3,702.22 -9,231.55 6,744.83 6,018,565.53 540,389.65 0.00 10,837.33 13,700.00 89.40 125.27 3,761.87 3,703.27 -9,289.29 6,826.47 6,018,508.17 540,471.55 0.00 10,937.32 13,800.00 89.40 125.27 3,762.92 3,704.32 -9,347.02 6,908.11 6,018,450.80 540,553.44 0.00 11,037.32 13,900.00 89.40 125.27 3,763.97 3,705.37 -9,404.76 6,989.76 6,018,393.44 540,635.34 0.00 11,137.31 14,000.00 89.40 125.27 3,765.02 3,706.42 -9,462.50 7,071.40 6,018,336.08 540,717.23 0.00 11,237.30 14,100.00 89.40 125.27 3,766.07 3,707.47 -9,520.23 7,153.04 6,018,278.72 540,799.12 0.00 11,337.30 14,200.00 89.40 125.27 3,767.12 3,708.52 -9,577.97 7,234.68 6,018,221.36 540,881.02 0.00 11,437.29 14,300.00 89.40 125.27 3,768.17 3,709.57 -9,635.70 7,316.33 6,018,164.00 540,962.91 0.00 11,537.29 14,400.00 89.40 125.27 3,769.22 3,710.62 -9,693.44 7,397.97 6,018,106.64 541,044.81 0.00 11,637.28 14,500.00 89.40 125.27 3,770.27 3,711.67 -9,751.17 7,479.61 6,018,049.28 541,126.70 0.00 11,737.28 14,600.00 89.40 125.27 3,771.32 3,712.72 -9,808.91 7,561.25 6,017,991.92 541,208.60 0.00 11,837.27 14,700.00 89.40 125.27 3,772.37 3,713.77 -9,866.65 7,642.90 6,017,934.56 541,290.49 0.00 11,937.27 14,800.00 89.40 125.27 3,773.42 3,714.82 -9,924.38 7,724.54 6,017,877.20 541,372.38 0.00 12,037.26 14,900.00 89.40 125.27 3,774.47 3,715.87 -9,982.12 7,806.18 6,017,819.84 541,454.28 0.00 12,137.25 15,000.00 89.40 125.27 3,775.52 3,716.92 -10,039.85 7,887.82 6,017,762.48 541,536.17 0.00 12,237.25 15,100.00 89.40 125.27 3,776.57 3,717.97 -10,097.59 7,969.46 6,017,705.12 541,618.07 0.00 12,337.24 15,200.00 89.40 125.27 3,777.62 3,719.02 -10,155.33 8,051.11 6,017,647.76 541,699.96 0.00 12,437.24 15,300.00 89.40 125.27 3,778.67 3,720.07 -10,213.06 8,132.75 6,017,590.39 541,781.86 0.00 12,537.23 15,400.00 89.40 125.27 3,779.72 3,721.12 -10,270.80 8,214.39 6,017,533.03 541,863.75 0.00 12,637.23 15,500.00 89.40 125.27 3,780.77 3,722.17 -10,328.53 8,296.03 6,017,475.67 541,945.64 0.00 12,737.22 15,600.00 89.40 125.27 3,781.82 3,723.22 -10,386.27 8,377.68 6,017,418.31 542,027.54 0.00 12,837.22 15,700.00 89.40 125.27 3,782.87 3,724.27 -10,444.00 8,459.32 6,017,360.95 542,109.43 0.00 12,937.21 15,800.00 89.40 125.27 3,783.92 3,725.32 -10,501.74 8,540.96 6,017,303.59 542,191.33 0.00 13,037.21 15,900.00 89.40 125.27 3,784.97 3,726.37 -10,559.48 8,622.60 6,017,246.23 542,273.22 0.00 13,137.20 16,000.00 89.40 125.27 3,786.02 3,727.42 -10,617.21 8,704.25 6,017,188.87 542,355.12 0.00 13,237.19 16,100.00 89.40 125.27 3,787.07 3,728.47 -10,674.95 8,785.89 6,017,131.51 542,437.01 0.00 13,337.19 16,200.00 89.40 125.27 3,788.12 3,729.52 -10,732.68 8,867.53 6,017,074.15 542,518.90 0.00 13,437.18 16,300.00 89.40 125.27 3,789.17 3,730.57 -10,790.42 8,949.17 6,017,016.79 542,600.80 0.00 13,537.18 16,400.00 89.40 125.27 3,790.22 3,731.62 -10,848.16 9,030.82 6,016,959.43 542,682.69 0.00 13,637.17 4242019 11:55:08AM Page 6 COMPASS 5000.15 Build 91 Planned Survey Halliburton HALLI B U RTO N Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Plan: MPU M-18 Company: Hilcorp Alaska, LLC TVD Reference: MPU M-18 Prelim Planned RKB @ 58.60usft Project: Milne Point MD Reference: MPU M-18 Prelim Planned RKB @ 58.60usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-18 Survey Calculation Method: Minimum Curvature Wellborn! MPU M-18 - Custer Easting DLS Vert Section Design: MPU M-18 wp06 (0) (usft) Planned Survey Measured Vertical Measured Hole Vertical Depth Depth Map Map Diameter Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 3,732.67 9-5/8 16,500.00 89.40 125.27 3,791.27 3,732.67 -10,905.89 9,112.46 6,016,902.07 542,764.59 0.00 13,737.17 16,600.00 89.40 125.27 3,792.32 3,733.72 -10,963.63 9,194.10 6,016,844.71 542,846.48 0.00 13,837.16 16,700.00 89.40 125.27 3,793.37 3,734.77 -11,021.36 9,275.74 6,016,787.34 542,928.38 0.00 13,937.16 16,721.52 89.40 125.27 3,793.60 3,735.00 -11,033.79 9,293.31 6,016,775.00 542,946.00 0.00 13,958.67 Total Depth : 16721.52' MD, 3793.6' TVD - 6 518" 8 112" Start Dir 4-1100': 550' MD, 549.51'TVD 750.00 745.94 Targets 16.90 Start Dir 5'/100': 750' MD, 745.94'TVD 1,805.58 1,515.35 -686.92 205.17 Target Name 6,728.97 3,413.35 -5,066.82 1,410.96 Start Dir 4-/100': 6728.97' MD, 3413.35'TVD - hit/miss target 3,672.45 Dip Angle Dip Dir. TVD +N/ -S +EI -W Northing Easting -Shape -6,042.36 2,235.10 (") (") (usft) (usft) (usft) (usft) (usft) M-18 wp05 Toe End Dir : 8186.04' MD, 3703.97' TVD 0.00 0.00 3,793.60 -11,033.79 9,293.31 6,016,775.00 542,946.00 - plan hits target center - Circle (radius 50.00) M-18 Heel wp03 0.00 0.00 3,698-60 -6,042.36 2,235.09 6,021,734.00 535,866.00 - plan hits target center - Circle (radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 16,721.52 3,793.60 65/8"81/2" 6-5/8 8-1/2 8,076.08 3,698.60 95/8"x121/4" 9-5/8 12-1/4 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +FJ -W (usft) (usft) (usft) (usft) Comment 330.00 330.00 0.00 0.00 Start Dir 30/100': 330' MD, 330'TVD 550.00 549.51 -11.89 4.33 Start Dir 4-1100': 550' MD, 549.51'TVD 750.00 745.94 -46.44 16.90 Start Dir 5'/100': 750' MD, 745.94'TVD 1,805.58 1,515.35 -686.92 205.17 End Dir : 1805.58' MD, 1515.35' TVD 6,728.97 3,413.35 -5,066.82 1,410.96 Start Dir 4-/100': 6728.97' MD, 3413.35'TVD 7,776.08 3,672.45 -5,869.80 1,991.09 End Dir : 7776.08' MD, 3672.45' TVD 8,076.08 3,698.60 -6,042.36 2,235.10 Start Dir 40/100' : 8076.08' MD, 3698.6'TVD 8,186.04 3,703.97 -6,105.76 2,324.75 End Dir : 8186.04' MD, 3703.97' TVD 16,721.52 3,793.60 -11,033.79 9,293.31 Total Depth: 16721.52' MD, 3793.6' TVD 4242019 11:55:08AM Page 7 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-18 MPU M-18 -Custer MPU M-18 wp06 Sperry Drilling Services Clearance Summary Anticollision Report 24 April, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt Moose Pad -Plan; MPD M-18 - MPU M-18 -Custer - MPU M-18 wpO6 Well Coordinates: 6,02],]65.60 N, 533,603,85 E (]0° 29' 12.79" N, 149° 43' 31.24" W) Datum Height: MPU M-18 Prelim Planned RKB @ 58.60usft Scan Range: 33.70 to 8,076.08 ustt. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usX Geodetic Scale Factor Applied Version: 5000.15 Build 91 Scan Type: Sean Type: 2500 HALLIBURTON Sperry Drilling Services HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU M-18 - MPU M-18 wp06 Backup Proposal: MPU M-XX(IRA) - Slot 17 -Wellbore, 308.70 Closest Approach 3D Proximity Scan an Current Survey Data (North Reference) 308.70 56.97 308.80 20.759 Centre Distance Reference Design: MPt Moose Pad -Plan: MPU M.18 -MPU M -18 -Custer -MPU M.18wp06 BackupPmpasal: MPU M-XX(IRA) - Slot 17-Wellbor, 358.70 5993 358.70 Scan Range: 33.70 to 8,076.08 usft. Measured Depth. 358.80 18.516 Ellipse Separation Pass - Backup Proposal:MPU M-XX(IRA)-Slot 17-Wellbor Scan Radius Is Unlimited. Clearance Factor outoa Is Unlimited. Max Ellipse Separation Is 1,000.00 tall 72.36 633.70 67.18 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 576.16 Sae Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usa 234.72 583.70 M Pt J Pad 607.92 52.693 Ellipse Separation Peas - MPU M -04 -MPU M -04 -MPU M-04 M Pt M Pad 315.32 1,183.70 305.91 121437 M -01 -M -01-M-01 5,83951 537.44 5,839.51 404.91 3,653.84 4.055 Centre Distance Pass - M -01 -M -01-M-01 5,93370 539.16 5,933.70 403.30 3,737.04 3.969 Ellipse Sepamb.n Pass - M -01 -M -01-M-01 6,058.70 546.87 6,05830 407.T 3,846.36 3.932 Clearance Factor Pass - M -01 -M -01A -M -01A 17.139 Ellipse Separation Pass - Plan :MPU M-07MW-MPU M-07(WSW -M-07WS 1,333.70 M-01-M-aIA-M-01A 1,333.70 ®l® 1,410.14 16.241 Clearance Factor M -01 -M -01A -M -01A 7,033.75 121.66 7,03375 1.71 4,876.18 1.014 Centre Distance Penn - M Pt Moose Pad Backup Proposal: MPU M-XX(IRA) - Slot 17 -Wellbore, 308.70 59.86 308.70 56.97 308.80 20.759 Centre Distance Pass - BackupPmpasal: MPU M-XX(IRA) - Slot 17-Wellbor, 358.70 5993 358.70 5610 358.80 18.516 Ellipse Separation Pass - Backup Proposal:MPU M-XX(IRA)-Slot 17-Wellbor 633.70 72.36 633.70 67.18 632.43 13.975 Clearance Factor Pass - MPU M -04 -MPU M -O4 -MPU M-04 576.16 234.70 576.16 230.30 600.18 53.331 Centre Distance Pass - MPU M -04 -MPU M -04 -MPU M-04 583.70 234.72 583.70 230.26 607.92 52.693 Ellipse Separation Peas - MPU M -04 -MPU M -04 -MPU M-04 1,183.70 315.32 1,183.70 305.91 121437 33.494 Clearance Factor Pass- Plan: MPU MnMSW-MPU M-07(WSW)-M-07WS 1,174.97 161.43 1,174.97 152.07 1,261.49 17.248 Centre Distance Pass - Plan :MPU M-07WSW-MPU M-07 (WSW) - MMS 1,183.70 161.49 1,183.70 15207 1,270.02 17.139 Ellipse Separation Pass - Plan :MPU M-07MW-MPU M-07(WSW -M-07WS 1,333.70 184.36 1,333.70 173.01 1,410.14 16.241 Clearance Factor Pass - Plan: MPU M -15i -M -15i -M -15i wp04 796.73 202.38 796.73 195.56 783.00 29.649 Centre Distance Pass - Plan: MPU M -15i -M -15i -M -15i wp04 833.70 202.56 833.70 195.45 818.09 28.491 Ellipse Separation Pass - Plan: MPU M-1 5i - M-1 5i - M-1 5i wp04 1,983.70 428.26 1,983.70 405.58 1,946.02 18.886 Clearance Factor Pass - Plan: MPU M-1 5i P2 - M-15 Phase 2 - M -15i P2 wp02 778.39 235.66 778.39 229.05 758.20 35.696 Centre Distance Pass - Plan: MPU M-15iP2 - M-15 Phase 2 - M-151 P2 wp02 808.70 235.76 808.70 228.92 785.79 34.460 Ellipse Separation Pass - Plan: MPU M -15i P2 - M-15 Phase 2 - W15i P2 wp02 2,208.70 469.11 2,208.70 434.95 2,084.03 13.732 Clearance Factor Pass - Plan: MPU M46 -MPU M -I6 -MPU M-16 wF06 723.20 114.78 723.20 109.00 717.35 19.854 Centre Distance pass - Plan :MPU M -I6 -MPU M -16 -MPU M-16 wp05 783.70 115.06 783.70 108.81 716.71 18.413 Ellipse Separation Pass - Plan :MPU M -I6 -MPU M -16 -MPU M-16 wp05 6,183.70 1,174.08 6,183.70 1,046.37 6,000.00 9.193 Clearance Factor Pass - 24 Apol, 2019 - 12:59 Page 2 of 7 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU M -18 -MPU M-18 wp06 261.37 60.16 261.37 57.18 Closest Approach 3D Proximity Scan an Current Survey Data (North Reference) 20.211 Centre Distance Pass - Plan: MPU M -17i P2 -M112 Phase 2-M-171 P2 wp02 30870 Reference Design: Is Pt Moose Pad - Plan: MPU M -I8 - MPU M-18 - Custer - MPU M-18 wp06 308.70 56.92 308.49 18.202 Ellipse Separation Scan Range: 33.70 to 8,076.08 usft. Measured Depth. Plan: MPU M-17iP2 - M112 Phase 2- M-171 P2 wp02 3.533.70 270.18 3,533.70 Soon Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 3.482.49 3.332 Clearance Factor Pass - Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 26.40 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation blaming Comparison Well Name -Wellbore Name - Design (usft) lush) (usft) (usft) usft 2,292.68 1.815 Ellipse Separation Plan: MPU M-16 P2 -M-16 Phase 2 -MPU M-16 P2 657.03 148.07 657.03 142.36 648.56 25.932 Centre Distance Pass - Plan :MPU M-16 P2 -M-16 Phase 2 -MPU M-16 P2 783.70 148.56 783.70 14188 770.94 22260 Ellipse Separation Pass - Plan: MPU M -16P2 -M-16 Phase 2 -MPU M-16 P2w 5,458.70 937.40 5,458.70 821.32 5,384.35 8.075 Clearance Factor Pass - Plan: MPU M -171 -MPU M -17i -MPU MIA wp04 522.07 29.08 522.07 24.73 521.50 6,683 Centre Distance Pass - Plan: MPU M -17i -MPU M -17i -MPU M-17 wp04 633.70 29.51 633.70 24.37 632.87 5.742 Ellipse Separation Pass - Plan: MPU M -17i -MPU M -17i -MPU M-17 wp04 6,50870 574.84 6,508.70 429.82 6,500.00 3.964 Clearance Factor Pass - Plan: MPU M -IT P2 -M112 Phase 2 -M -17i P2 wp02 261.37 60.16 261.37 57.18 261.47 20.211 Centre Distance Pass - Plan: MPU M -17i P2 -M112 Phase 2-M-171 P2 wp02 30870 60.23 308.70 56.92 308.49 18.202 Ellipse Separation Pass - Plan: MPU M-17iP2 - M112 Phase 2- M-171 P2 wp02 3.533.70 270.18 3,533.70 189.09 3.482.49 3.332 Clearance Factor Pass - Plan: MPU M-18 P2 - M-18 P2 - M-18 P2 wp03 368.70 29.67 368.70 26.40 365.01 9.066 Centre Distance Pass - Plan: MPU M-18 P2 -M-18 P2 -M-18 P2 wp03 2,308.70 54.96 2,308.70 24.69 2,292.68 1.815 Ellipse Separation Pass - Plan: MPU M-18 P2 -M-18 P2 -M-18 P2 wp03 7,333.70 188.37 7,333.70 63.13 7,269.23 1.504 Clearance Factor Pass- Plan : MPU M -191 -MPU M -19i -Jet, Stuart - MPU M-1 412.75 89.50 412.75 85.92 410.18 25.038 Centre Distance Pass - Plan: MPU M -19i -MPU M -19i -Jab Stuart - MPU M-1 508.70 89.81 508.70 85.58 506.96 21.197 Ellipse Separation Pass - Plan: MPU M -19i -MPU M -19i -Job Stuart - MPU M-1 7,333.70 546.01 7,333.70 380.18 7,29483 3.293 Clearance Factor Pass - Plan :MPUM-19i P2 -M -19i P2 -M -19i P2wp02 333.70 119.86 333.70 116.82 329.81 39.477 Centre Distance Pass - Plan: MPU M -19i P2 -M -19i P2 -M -19i P2 wp02 358]0 119.93 358.70 116.73 354.81 37.427 Ellipse Separation Pass - Plan: MPU M-1 9i P2 -M -19i P2 -M -19i P2 wp02 7,658.70 601.48 7,658.70 416.60 7,611.50 3.253 Clearance Factor Pass- Plan: MPU M -20 -M -20-M-20 wp02 308.70 269.99 308.70 26711 308.80 93.647 Centre Distance Pass- Plan- MPU M -20 -M -20-M-20 wp02 408.70 27021 408.70 266.62 408.08 75.402 Ellipse Separation Pass - Plan :MPU M -20 -M -20-M-20 WP02 7,083.70 484.69 7,083.70 312.98 10,287.67 2.823 Clearance Factor Pass - Plan: MPU M-20 P2 - M-20 Phase 2- M-20 P2 wpO3 30810 297.45 308.70 294.13 308.80 89308 Centre Distance Pass - Plan :MPU M-20 P2 -M-20 Phase 2-M-20 P2 wp03 6,85870 393.63 6,858.70 225.98 9,741.90 2.348 Ellipse Separation Pass - Plan:MPU M-20 P2 -M-20 Phase 2-M-20 P2 wp03 6,933.70 407.37 6,933.70 231.08 9,804.78 2.311 Clearance Factor Pass- Plan : MPU M-21 i - M-21 i - M-21 i wp02 308.70 195.01 308.70 192.12 308.80 67.631 Centre Distance Pace - Plan; MPU M -21i -M -211 -M -21i wp02 358.70 195.08 358.70 191.84 358.80 60.262 Ellipse Separation Pass - Plan :MPU M -211 -M -21i -M -21i wp02 6,88370 1,162.79 6,88370 1,000.79 9,543.95 7.177 Clearance Factor Pass - Plan: MPU M -21i P2 -M-211 Phase 2 -M -21i P2 wp02 308.70 172.97 308.70 169.65 308.80 52.166 Centre Distance Pass - Plan:MPU M -21i P2 -M -21i Phase 2 -M -21i P2 wp02 358.70 173.06 358.70 169.39 358.80 47.161 Ellipse Separation Pa" - Plan :MPU M -21i P2 -M -21i Phase 2 -M -21i P2 wp02 6,833.70 1,244.33 6,833.70 1,074.99 9,332.47 7.348 Clearance Factor Pass - 24 Apd/, 2019 - 12:59 Page 3 of 7 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU M-18- MPU M-18 wp06 308.70 127.94 308.70 125.06 Closest Approach 30 Proximity Scan on Current Survey Data (North Reference) 44.372 Centre Distance Pass - Plan: MPU M -23i - M -23i - M -23i wp02 Reference Design: MPt MoosePad - Plan: MPU M -I8 -MPU M -18 -Custer -MPU M-18 wp06 127.95 333.70 124.89 333.80 Scan Range: 33.70 to 8,076.08 usft. Measured Depth. Ellipse Separation Pass - Plan: MPU M -23i - M-231 - M -23i wp02 583.70 Seen Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 583.70 148.79 569.07 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 308.70 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 333.70 138.07 Plan: MPU M -22 -M -22-M-22 wp02 308.70 138.19 308.70 135.23 308.80 46.676 Centre Distance Pass - Plan: MPU M-22 - M-22 - M-22 wp02 358.70 138.34 358.70 134.97 358.80 41.080 Ellipse Separation Pass - Plan: MPU M -22 -M -22-M-22 wp02 633.70 167.92 633.70 162.37 616.05 30.263 Clearance Factor Pass - Plan: MPU M-22 P2 - M-22 Phase 2 - M-22 P2 Wp02 308.70 128.01 308.70 124.70 308.80 38.608 Centre Distance Pass - Plan: MPU M-22 P2 - M-22 Phase 2 - M-22 P2 wp02 333.70 128.02 333.70 124.52 333.80 36.635 Ellipse Separation Pass - Plan: MPU M-22 P2 - M-22 Phase 2 - M-22 P2 wp ]2 558.70 148.84 558.70 143.78 545.26 29.416 Clearance Factor Pass - Plan : MPU M -231 -M -23i -M -23i wp02 308.70 127.94 308.70 125.06 308.80 44.372 Centre Distance Pass - Plan: MPU M -23i - M -23i - M -23i wp02 333.70 127.95 333.70 124.89 333.80 41.784 Ellipse Separation Pass - Plan: MPU M -23i - M-231 - M -23i wp02 583.70 153.59 583.70 148.79 569.07 31.977 Clearance Factor Pass - Plan: MPU M -23i P2 - M-231 Phase 2 - M -23i P2 rp02 308.70 138.06 308.70 134.75 308.80 41.639 Centre Distance Pass - Plan: MPU M -23i P2 - M -23i Phase 2 - M -23i P2 wp02 333.70 138.07 333.70 134.57 333.80 39.511 Ellipse Separation Pass - Plan: MPU M -23i P2 - M -23i Phase 2 - M -23i P2 Wp02 558.70 160.15 558.70 155.10 544.11 31.686 Clearance Factor Pass - Plan: MPU M -24 -M -24-M-24 wp02 308.70 172.76 308.70 169.71 30RAD 56.650 Centre Distance Pass - Plan: MPU M-24 - M-24 - M-24 wp02 333.70 172.76 333.70 169.52 333.80 53.266 Ellipse Separation Pass - Plan: MPU M-24 - M-24 - M-24 wpg2 633.70 208.23 633.70 202.73 610.33 37.876 Clearance Factor Pass - Plan: MPU M-24 P2 -M-24 Phase 2-M-24 P2 wp02 308.70 194.78 308.70 191.46 308.80 58.744 Centre Distance Pass - Plan: MPU M-24 P2 - M-24 Phase 2 - M-24 P2 wp02 333.70 194.78 333.70 191.29 333.47 55.762 Ellipse Separation Pass - Plan: MPU M-24 P2 - M-24 Phase 2 - M-24 P2 wp02 633.70 237.17 633.70 231.65 600.00 42.949 Clearance Factor Pass - Plan : MPU M -25i -M -25i -M -25i wp03 308.70 153.47 308.70 150.59 308.80 53.225 Centre Distance Pass - Plan: MPU M -25i -M -25i -M -25i wp03 333.70 153.47 333.70 150.41 333.80 50.121 Ellipse Separation Pass - Plan: MPUM-25i-M-251-M-251 wp03 633.70 181.30 633.70 176.15 620.00 35.175 Clearance Factor Pass - Plan: MPU M -25i P2 - M -25i Phase 2 - M -25i P2 wp02 261.37 218.70 261.37 215.73 261.47 73.479 Centre Distance Pass - Plan: MPU M -25i P2 - M -25i Phase 2 - M -25i P2 wp02 283.70 218.71 283.70 215.57 283.44 69.759 Ellipse Separable, Pass - Plan: MPU M -25i P2 - M -25i Phase 2- M-251 P2 Wp02 633.70 266.58 633.70 261.09 591.29 48.550 Clearance Factor Pass - Plan: MPU M -26 -M -26-M-26 wp03 308.70 149.87 308.70 14698 308.80 51.975 Centre Distance Pass - Plan :MPU M-26-M-26-M-2fi wp03 358.70 150.03 358.70 146.80 357.43 46.431 Ellipse Separation Pass - Plan: MPUM-26-M-2fi-M-26 wpO3 658.70 186.42 658.70 181.17 630.02 35.476 Clearance Factor Pass - Plan :MPU M-26 P2 -M-26 Phase 2-M-26 P2 wp02 261.37 179.87 261.37 176.89 261.47 60.432 Centre Distance Pass - Plan: MPU M-26 P2 - M-26 Phase 2 - M-26 P2 wp02 308]0 180.02 308.70 176.72 306.85 54.418 Ellipse Separation Pass - Plan: MPUM-26 P2 -M-26 Phase 2-M-26 P2 wp02 658.70 220.05 658.70 214.38 624.34 38.783 Clearance Factor Pass - 24 April, 2019 - 12:59 Page 4 a7 COMPASS HALLIBURTON Hileorp Alaska, LLC Milne Point Anticollislon Report for Plan: MPU M-18 - MPU M-18 wp06 From To SurveylPlan Survey Tool (oaft) (usft) Closest Approach 30 Proximity Scan on Current Survey Data (North Reference) 33.70 8,076.08 MPU M-18 wp06 2_MWD+IFR2+MS+Sag 8,07608 16,721.29 MPU M-18 wp06 2_MWD+IFR2+MS+Sag Reference Design: M Pt Moose Pad - Plan: MPU M-10 - MPU M-18 - Luster - MPU M-18 WP06 Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Scan Range: 33.70 to 8,076.08 usft. Measured Depth. Distance Between centres Is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Sepamtion). Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Proposal: MPU M-08DSW-Mclaws-M-08DSW-Mc 1,457.36 42.29 1,457.36 32.51 1,523.90 4.326 Centre Distance Pass - Proposal: MPU M-08DSW-MCLaws-M-08DSW-Mc 1,483.70 43.36 1,483.70 31.58 1,549.36 3.682 Ellipse Separation Pass - Proposal: MPU M-08DSW-MCLaws-M-08DSW-Mc 1,533.70 50.81 1,533]0 34.81 1,597.31 3.175 Clearance Factor Pass- Proposai:M-XX(IRA)-Slot 22-Wellbore#1-M-XX-t 308.70 124.41 308.70 121.53 308.80 43.148 Centre Distance Pass - Proposal: M-XX(IRA)-Slot 22- Welborn #1 -M -XX -t 333.70 124.42 333.70 121.35 333.80 40.631 Ellipse Separation Pass - Proposal: M-XX(IRA)-Slot 22-Wellbore#1-M-XX-t 683.70 156.93 683.70 151.39 681.52 28.328 Clearance Factor Pass - M Pt N Pad Survey tool Drogram From To SurveylPlan Survey Tool (oaft) (usft) 33.70 8,076.08 MPU M-18 wp06 2_MWD+IFR2+MS+Sag 8,07608 16,721.29 MPU M-18 wp06 2_MWD+IFR2+MS+Sag Ellipse error terms are correlated across survey tool fie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres Is the straight line distance between wellbore centres. Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Sepamtion). All station coordinates were calculated using the Minimum Curvature method. 24 Apol, 2019 - 12:59 Page 5 of COMPASS MALLIBURTON Project: Milne Point I I REFERENCE INFORMATION _ DETAnTsYTn: M?RI R NAD 19271TADOON"CO\1G9) Alu4v]retW Site: MPt Moose Pao �� rvi81Ne1 am.�„r6 uP'iw.Meu v4.96 sr.•w umurve Well: ro—o.N vewy m"fay,,.,Ke.. 1wlerr.w PN..e Rws®sezrvn w,.�....-Noo. uwfew.m. e.�.maim®usmn -e�-u Noe6ms FuinH vau�wr wave MPUMPUM-18 Wellbore: MPUM-18-Custer r'N.. oon �,..wm c.awK am a.w 6azn6s 6a tvaaret To- 111 wr mvl x+uv x' Plan: MPU M-18 wP06 SUN�Y PROGRAM NO GLOBAL FILTER: UsIIp user deMned s don 8 stern, ofterna ® Dam: mts.ox-ssT":m:a' VelitleRa: ns versmn: 33 70 To 18]31.04 Oap15 Fmm '8015 To survey?len Tool CASING D£rAILS Ladder/S.F. Plots J3]' 5']605 MPU x ] FNlD+IFfl2+M5+5ap M R 06 80]808 16]x1 ]9 MPU M-16 xp'fi x MJJ'�IFRNMS�Sp WD TVDSS MO $1u Nom. SH (1 of 2) JN1 3640.00 80 9-5/8 SR'a131/4" 16]]]6.09 5:9 6518'91R" J]9360 JD500 151 4 6 5600 � 8%2v+A0 M -23i p2 li 6120,Fol 00- - '$ M-1 P2 o MPU -18 wp05 MP M-19 •'994 m 90.00 a I.4XX opOl IRA Kfyafuk- g61dMA4 Is y k9-1]3 I m 02 _ 'A4 _ - . M-ta P20] � � 60,00 N U 9 I rVU 30.00 MPU -n rma4 o.1D 0 425 a50 1275 1700 2125 2550 2975 3401 3825 4250 4675 5100 5525 5950 6375 6 0 ]225 ]650 8075 Measured Depth (850 usltrin) 4.09 u5 3.00 1 I LL I Collision Risk Procedures Req. A zpp n m Collision Avoidance Req.'. y 1.00 N1 -Go Zone - Stop Drilling '. " I NOERRORS j 0.00 0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 5525 5950 6375 6000 7225 7650 W75 Measured Depth (850 usftrin) Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-18 MPU M-18 - Custer MPU M-18 wp06 Sperry Drilling Services Clearance Summary Anticollision Report 24 April, 2019 Closest Approach 30 Proximity Scan on Current Survey Data (North Reference) Reference Design: MPt Moose Pad -Plan: MPU M -18 -MPU M -18 -Custer -MPU M-18 wp06 Well Coordinates: 6,027,765.60 N, 533,603.85 E (70° 29' 12 79" N, 149° 43' 31.24" W) Datum Height: MPU M-18 Prelim Planned RKB @ 58.60usft Scan Range: 8,076.08 to 16,721,52 usff. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usff Geodetic Scale Factor Applied Version: 5000.15 Build 91 Scan Type: Scan Type: 2500 HALLIBURTON Sperry Drilling Services Hilcorp Alaska, LLC HALLIBURTON 16,003.06 1,162.21 16,003.06 559.25 Milne Point Anticollision Report for Plan: MPU M-18 - MPU M-18 wp06 Pass - MPJ-24-MPJ-24Li PB2-MPJ-24L1 P82 16,076.08 1,164.51 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 556.77 11,115.00 1.916 Ellipse Separation Pass - MPJ-24-MPJ-24LIPB2-MPJ-24Li PB2 Reference Design: MPtMoosePad - Plan: MPU M -18 -MPU M -18 -Custer -MPU M-18wp06 1,166.34 16,101.08 557.50 11,115.00 1.916 Clearance Factor Scan Range: 8,076.08 to 16,721.52 usft. Measured Depth. MPJ -24 -MPU J -24 -MPJ -24 Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft - MPJ -24 -MPU J -24 -MPJ -24 Measured Minimum @Measured Ellipse @lMeasumd Clearance Summary Based on -- Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (usft) (usft) (usft) (usft) usft 16,611.16 135.70 M Pt J Pad 52.24 11,178.41 1.626 Centre Distance Pass - MPJ -27 -MPJ -27 -MPJ -27 MPJ-20-MP120A-MPb20A 16,721,52 531.14 16,721.52 270.04 11,176.00 2.034 Clearance Factor Pass - MPbM-MPJ-23-MP123 16.721.52 1,481.51 16,721.52 865.04 10,607.35 2.403 Clearance Factor Pass- MPJ-23-MPJ-23A-MP123A 16,721.52 1,209.53 16,721.52 70301 10,704]0 2.388 Clearance Factor Pass- MPJ-23-MPb23LI-MPJ 23L1 16,721.52 1,495.03 16,721.52 933.86 10,702.27 2.664 Clearance Factor Pass - MPJ -24 -MPJ -24A -MPJ -24A 14,64096 157.98 14,640.96 66.37 12,800.98 1.724 Cenlre Distance Pass - MPJ -24 - MPJ -24A - MP.424A M Pt Moose Pad - MPJ -24 -MPJ -24A -MPJ -24A - - Plan: MPU M -17i -MPU M -17i -MPU M-17 wp04 -- 742.29 MPJ -24 -MPJ -241 -1 -MPJ -24L1 - - 1.493 Clearance Factor - Plan:MPU M -17i P2 -M112 Phase 2 -M -17i P2 wp02 MPJ-24-MPJ-24Li-MPJ-24L1 834.13 8,076.08 632.61 -- 4.139 Centre Distance MPJ-24-MPJ-24LiPB1-MPJ-24L1PB1 16,235.11 1,250.84 16,235.11 638.84 10,867.00 2.044 Cenlre Distance Pass - MPJ-24-MPJ-24Li P81-MPJ-24L1Pel 16,301.08 1,252.58 16,301.08 636.23 10,867.00 2.032 Ellipse Separation Pass - MPJ -24 -MPJ -24L1 PB1-MPJ-24L1 PBI 16,326.08 1,254.15 16,326.011 636.58 10,867.00 2.031 Clearance Factor Pass - MPJ-24-MPJ-24LIPB2-MPJ-24L1PB2 16,003.06 1,162.21 16,003.06 559.25 11,115.00 1.927 Centre Distance Pass - MPJ-24-MPJ-24Li PB2-MPJ-24L1 P82 16,076.08 1,164.51 16,076.08 556.77 11,115.00 1.916 Ellipse Separation Pass - MPJ-24-MPJ-24LIPB2-MPJ-24Li PB2 16,101.08 1,166.34 16,101.08 557.50 11,115.00 1.916 Clearance Factor Pass - MPJ -24 -MPU J -24 -MPJ -24 - MPJ -24 -MPU J -24 -MPJ -24 -- MPJ -27 -MPJ -27 -MPJ -27 -- MPJ-27-MPJ-27-MPJ-27 16,611.16 135.70 16,611.16 52.24 11,178.41 1.626 Centre Distance Pass - MPJ -27 -MPJ -27 -MPJ -27 -- M Pt M Pad M -01 -M4)1 -M-01 8,076.08 992.69 8,07608 921.15 5,487.88 13.876 Clearance Factor Pass- M411-M-01A-NL01A 8,076.08 772.28 8,076.08 501.23 5,577.42 2.849 Clearance Factor Pass - M Pt Moose Pad Plan: MPU M -17i -MPU M -17i -MPU M-17 wp04 16,721.52 742.29 16,721.52 244.95 16,474.86 1.493 Clearance Factor Pass - Plan:MPU M -17i P2 -M112 Phase 2 -M -17i P2 wp02 8,076.08 834.13 8,076.08 632.61 7,643.64 4.139 Centre Distance Pass- 24APn1, 2019 - 13:01 Page 2 075 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU M-18 - MPU M-18 wp06 8,07608 795.90 8,076.08 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 7,934.20 3.571 Centre Distance Pass - Reference Design: M Pt Moose Pad - Plan: MPU M-18 -MPU M-18 - Custer - MPU M-18 wp06 13,551.08 83934 13,551.08 Scan Range: 8,076.08 to 16,721.52 usft. Measured Depth. 13,800.00 2.057 Ellipse Separation Pass - Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 13,626.08 847.37 Measured Minimum @Measamid Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usfl 5.496 Clearance Factor Plan -MPU M -17i P2 -M112 Phase 2 -M -17i P2 wp02 12,851.08 867.49 12,851.08 488.82 12,418.40 2.291 Clearance Factor Pass - Plan: MPU M-18 P2 - M-18 P2 - M-18 P2 wp03 8,376.08 112.59 8,376.08 52.44 8,253.73 1.872 Ellipse Separation Pass - Plan: MPU M-18 P2 - M-18 P2 - M-18 P2 wp03 8,405.71 112.30 8,405.71 52.81 8,281.20 1.888 Centre Distance Pass - Plan: MPU M-18 P2 -M-18 P2 -M-18 P2 wp03 16,676.08 180.10 16,67608 74.27 16,500.00 1.702 Clearance Factor Pass - Plan; MPU M -19i -MPU M -19i -Jab Stuart - MPU MA 16,721.52 754.70 16,721.52 277.79 17,098.62 1.582 Clearance Factor Pass - Plan : MPU M -19i P2 -M -19i P2 -M-191 P2 wp02 8,07608 795.90 8,076.08 573.03 7,934.20 3.571 Centre Distance Pass - Plan: MPU M -19i P2-MAlb P2-MAgi P2 wp02 13,551.08 83934 13,551.08 431.30 13,800.00 2.057 Ellipse Separation Pass - Plan: MPU M -19i P2 -M -19i P2 -M -19i P2 wp02 13,626.08 847.37 13,626.08 435.14 13,859.02 2056 Clearance Factor Pass - Plan: MPU M-20 - M-20 - M-20 wp02 8,076.08 1,163.93 8,07605 952.16 10,908.29 5.496 Clearance Factor Pass - Plan: MPU M-20 - M-20 - M-20 wp02 8,076.08 1,163.93 8,076.08 952.16 10,908.29 5.496 Centre Distance Pass - Plan: MPU M-20 P2 -M-20 Phase 2-M-20 P2 wp03 8,07608 1,170.21 8,076.08 955.52 10,559.11 5.451 Clearance Factor Pass - M Pt N Pad Sulvey tool nrooram From To SurveylPlan Survey Tool (usft) (usft) 33.70 8,076.08 MPU M-18 wp06 2 MWD+IFR2+MS+Sag 8,076.08 16,721.29 MPU M-18 wpO6 2_MWD+IFR2+MS+Sag Ellipse error terms are correlated across survey tool tie -on points. Calwlmml ellipses incorporate surtace errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles /(Distance Between Profiles - Ellipse Separation). All station wordinatas were calculated using the Minimum Curvature method. 24 April, 2019 - 13:01 Page 3 of 5 COMPASS DEFERENCE INFORMATION N.EN'Nary WUM-I6 Nan r2 NACCONCUI.'VI NazYalp,e0! MALLIBURTON Project: Milne Point I usu Mlan„eu - Site: MPt Manse Pa.. r^uu— IRerarc.. sRe°rvnrnn°6 fiw58er.rerce: amu un6a�.um rl..wxlm®sesawn zaso Well: Plan: Ma.a�.m DaFU R.r..a�awuura Foam Narvei RlHaaa.aW.n *.,s .r, -u' X69 Swalw° t.o.si .1 Wellbore: MPU M -18 -Custer L1pi1a°"�a"1"o°,uw..K. a.av° aoo as mmas.69 sv605 es 71xv lz 79xsu I»°n•SI.zw7 Plan: MPU M-18 WP06 SURVEY PROGPAM NO GLOBAL FILTER: WTI, To Ee0ned mledNn dfiltenM cfieria PROGR5: Gate: 2019OD35T090P00 Yu Version: 3].,u To 1661.6 d Em Ladder/S.F. Plots Cann Fmrn OepN To aur ,rPlao Idol CAswo DE M s; 33.70 M16 as MPU Ejs MOfi R MWO.IFR3°M6�98 PH (2 of 2) 80]6.00 1672129 MPU M. ep08 TVD TVn85 MD sie, Name 5698.60 3610.00 8076.08 9518 959"x12114" 3M.W 373500 1672152 6-59 6518"81C" iso 00 J-21 0 0 oy2a.a9 m M W903 o` m 90,00 m CL v to N so.ao U o � I � 3600 ---�-- _ U ON 8100 0550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 13950 14400 14850 15300 15750 1fi200 16650 Measured Depth (900 usR/in) 4.00 o M�auo I ilN mCollision Risk Procedures Req. I j .00 2es es m Collision Avoidance Req. i 00 No -Go Zone -Stop Dulling NOERRORS 0 00 8100 8550 9000 9450 9900 10350 10000 11250 11700 12150 12600 13050 13500 13950 14400 14850 15300 15750 16200 16650 Measured Depth (900 usithn) Transform Points X Source coordinate system Target coordinate system State Plane 1927 - Alaska Zone d 1 (e c vF Albers Equal Area (-150) Datum: ItPG(, M—{g Datum: NAD 1927 - North America Datum of 1927 { can NAD 1927 - North America Datum of 1927 (Mean) Type values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to copy and Ctd+V to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: M P ((—N-13 PTD: 2. `i - © 7 0 development —Service —Exploratory _ Stratigraphic Test —Non -Conventional Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 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 Pilot Hole name ( PH) and API number (50- -_) from records, data and logs acquired for well name on permit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Com any Name) must contact the AOGCC to obtain advance approval of such water well testing program. 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 (Company Name) in the attached application, the following well logs are v/ also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V/ composite curves for well logs run must be submitted to the AOGCC within 90 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT M-18 Program DEV Well bore seg ❑ I PTD#:2190700 Comoanv HILCORP ALASKA LLC Initial Class/Type DEVI.PEND GeoArea 89_0 Unit 11328 On/Off Shore On Annular Disposal ❑I Administration '1 Permit fee attached .. - - - - - - _ _ _ _ _ _ . - - _ NA :2 Lease number appropriate_ - _ _ _ - .. _ _ . . . . . ... . . . . . .. . . . . ..... Yes . . 3 Unique well. name and number _ _ _ ______ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ Yes 4 Well located in a. defined pool . . . . . . . . . . . . . . ................... . .. Yes 5 .. Well located proper distance from drilling unit boundary.......... _ .. - - - - - - - - - Yes 6 Well located proper distance from other wells__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 7 Sufficient acreage available in drilling unit - - --------- - - - - - - - - - - - - - - - - - - - - Yes 8 If deviated, is wellbore plotincluded_ _ _ _ _ _ _ _ _ _ _ _ - _ _ . _ ... Yes 9 Operator only affected party. _ _ - - - - - - - - - - - - - - - - - - - - - - - - Yes 10 Operator hasappropriate bond in force _ _ _ _ _ _ - - Yes 11 Permit can be issued without conservation order. _ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 12 Permit can be issued without administrativeapproval_ _ .... Yes 13 Can permit be approved before 15 -day. Walt.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. Yes DLB 5/2/2019 14 Well located within area andstrata authorized by. Injection Order# (put lO# inoomments).(For NA 15 All wells. within 1/4 -mile area of review identified (For service well only) ........... . . . . NA 16 Pre -produced injector; duration of pre -production less than 3 months -(For service well -only) .. NA - - - - - - - - - 17 .Nonconven. gas conforms to AS31,05J03QQ.1.A),(j,2.A-D) - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - 18 Conductor string. provided - - - - - - - - - - - - - - - - - - - - - - - - - ------------ - - - - Yes _ 20" conductor set at 1138......... . Engineering 19 Surface casing, protects all known USDWs . ....... . . . . . .. . . . . . ... . . . . . . .. NA _ _ _ No aquifers. . _ ... _ 20 CMT vol adequate to circulate on conductor& surf csg ........................ Yes ... 9 5/8". surfece/prod.casing will be cemented with ES tool -at 2500 ft. _ 21 CMT. vol adequate to fie -in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 22 iCMT_will cover all known productive horizons. _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ __ Yes - 6 5/8" slotted liner will be set in Lateral section.... 23 Casing designs adequate for C, T, B &-permafrost... ............. Yes 24 Adequatelankage.or reserve pit _ _ _ _ ..... _ _ . . . . . ...... . . . . Yes _ _ _ Rig has steel pits... 25 Jf a -re -drill, has.a 10-403 for abandonment been approved . ......... . . . . NA 26 Adequate wellbore separation proposed__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Close approach to M-01 and J -24A.. Precautions needed whendrilling past......... 27 If diverter required, does it meet regulations.. - _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 28 Drilling fluid, program schematic & equip list adequate . . ............. . ........ Yes ....... Max formation press= 1627�psi -(8.5 ppg EMW) But could seepressure inlateraldue to offset injection. GLS 5/7/2019 29 BOPEs,.do they meet regulation . . . . . ............ . ........ . . . . . Yes.. _ - - - _ Using MPO for drilling lateral...._ 30 BOPE_press rating appropriate; test to (put prig in comments)_ _ _ Yes _ _ _ _ - MASP= 1257 psi - Will test BOPE to 3000 psi 31 Choke. manifold complies w/API-RP-53 (May 84). _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . . . . . . . . . . . .. . .... ....... . ......... . _ _ 32 Work will occur without operation shutdown.... _ Yes .. _ _ _ _ _ _ ....... _ ........... . ....... . . . . . . . _ _ 33 Is presence_of H2S gas probable . . . . . . . . . . . . . . ....... ....... . ....... Yes ....... H2$ on. pad ... Rig has sensors and alarms. 34 Mechanical.condit(on of wells within AOR verified (Forserv[ce well only) .............. NA...................... _ _ . 35 Permit can be issued w/o hydrogen sulfide measures _ _ ______ _ _ _ _ _ _ _ _ __ Yes .... _ .. H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms. Geology 36 Data. presented onpotentialoverpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 37 Seismic analysis of shallow gas zones. ... _ _ _ _ _ _ _ NA . . . . . . . . . ....................................... DLB 5/2/2019 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA.. 39 Contact name/phone for weekly progress reports [exploratory only] .......... . .. NA ........ Geologic Date: Engineering Date Public Date Moose Pad Jet pump well. Will be reverse circulating .... GIs. SSV will be in vertical run. Commissioner: Commissioner: Commissioner
