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Home My WebLink About220-017Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2025 InspectNo:susSTS250729151446 Well Pressures (psi): Date Inspected:7/25/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:4/15/2020 #320-163 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Chris Casey Date AOGCC Notified:7/18/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT S-56 Permit Number:2200170 Wellhead Condition Clean and no leaks. All valves turn easily Surrounding Surface Condition Fresh gravel around can. No debris or trash Condition of Cellar Dry and no contaminents Comments Location verified by plot map Supervisor Comments Photos (2) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, September 12, 2025 9 9 9 9 9 9 9 9 9 9 9 9 2025-0725_Suspend_MPU_S-56_photos_ss Page 1 of 1 Suspended Well Inspection – MPU S-56 PTD 2200170 AOGCC Inspection Rpt # susSTS250729151446 Photos by AOGCC Inspector S. Sullivan 7/2/2025 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect Well Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,500 feet 3,320 feet true vertical 4,022 feet N/A feet Effective Depth measured 3,320 feet feet true vertical 2,914 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2"9.3# / L-80 / EUE 8rd 2,784' 2,490' Packers and SSSV (type, measured and true vertical depth)N/A See Schematic N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: See Schematic See Schematic 777-8333 2. Operator Name 107' 5,363' measured Casing Senior Engineer: Senior Res. Engineer: Collapse 520psi 3,090psi Burst 1,530psi 5,750psi Liner N/A Conductor Size Junk Length Production 20" MILNE PT UNIT S-56 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-017 50-029-23669-01-00 Plugs ADL0380109 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data WINJ WAG Water-Bbl MD 107' measured 4,095'5,363' TVD 107' Oil-Bbl measured true vertical Packer See Schematic 9-5/8" 9,020psi 85,404psi5,686' 4-1/2" 11,086' 4,061' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:30 am, Oct 09, 2020 Chad A Helgeson 2020.10.08 16:14:42 -08'00' SFD 10/12/20200 RBDMS HEW 11/12/2020 MGR13OCT2020 DSR-10/12/2020 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA 0 OA NA Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm Follow Up Actions Needed: Hilcorp 220-017 Condition of Surrounding Surface Location: 04/15/20 320-163 REVIEWED BY: Other (specify in comments) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Brian Bixby 09/20/20 Yes Jon ArendMPS-56 (907)240-4383 Yes Onshore 09/18/20 Initial Good, Clean, No leaks Good, Clean None Monobore well, Location verified by Pad map WBS Pictures Area map Yes PLB 12/2014 MPS-56 Suspended Well Inspection 9-20-20 _____________________________________________________________________________________ Revised By: CJD 5/5/20 Schematic Milne Point Unit Well: MPU S-56 PTD: 220-017 API: 50-029-23669-00-00 Depth MD Depth TVD ICD/Swell Packer Detail 5,517’ 4,089’ Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 6,075’ 4,066’ Tendeka Water Swell Packer 6,588’ 4,053’ Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,020’ 4,061’ Tendeka Water Swell Packer 7,452’ 4,064’ Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,925’ 4,044’ Tendeka Water Swell Packer 8,482’ 4,035’ Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 8,994’ 4,047’ Tendeka Water Swell Packer 9,588’ 4,059’ Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 9,979’ 4,050’ Tendeka Water Swell Packer 10,779’ 4,054’ Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge TD =14,500’ (MD) / TD =4,021’ (TVD) 20” Cut at 5,400’ MD Orig. KB Elev.:63.5’/ GL Elev.:36.9’ 2 9-5/8” 1 3-1/2” 3 Hole in casing @ ±3,342’-3,386’ 15 bbls cmt on top of cmt retainer See ICD & Swell Packer Detail PBTD =14,500’ (MD) / PBTD =4,021’(TVD) 9-5/8” ‘ES’ Cementer @ 2,143’ MD Shoe @ 11,086’ MD 35 bbls below cmt retainer 4-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x 34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’N/A 9-5/8" Surface 40 / L-80 / TXP 8.679” Surface 5,363’ 0.0758 4-1/2” Liner (FISH)13.5 / L-80 / Hyd 625 3.795” 5,400’ 11,086’ 0.0149 Tubing Detail 3-1/2” Tubing Kill String 9.3# / L-80 / EUE 8RD 2.867” Surface 2,784’ 0.0087 JEWELRY DETAIL No Top MD Item ID 1 3,320’ Baker K1 CIBP - 2 5,282’ Cement Retainer 3 11,086’ Shoe 3.970” OPEN HOLE / CEMENT DETAIL 42" ±270 ft3 12-1/4"Stg 1 –Lead 418 sx/ Tail 418 sx Stg 2 –Lead 136 sx / Tail 270 sx 8-1/2”246 sx / 35 bbls below / 15 bbls above Cmt Retainer @ 5,282’ TOC @ ±5,102’ 8-1/2”FISH Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 416’ TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API#: 50-029-23669-00-00 Suspended by Innovation: 4/15/2020 Suspended WellInspection Review Report |nspecUNo: sus8DB200921131247 Date Inspected: 9/I0/2820 - Inspector: Brian Bixby - Type ofInspection Well Name: K4|LNE PT UNIT S-56 ~ � PennbNumber: � 2200170 ' Suspension Approval: Sundry - # 320-I63 - Suspension Date: 4/16/2020 Location Verified? |fVerified, How? Other (specify incomments) Offshore? El Initial ' Date A8G[[Notified: 9/18/2020 Operator: Hi|corpAlaska, LLC Operator Rep: Jon Arend Wellbore Diagram Avai|? Photos Taken? Well Pressures (psi): Tubing: 0 ' Fluid inCellar? [] |A: 0 - BPY|osteHed7 [] OA: VR Plug(s) Installed? El Wellhead Condition All of the valves on the appeared in good working order with working gauges on the Tubing, IA and OA. There asre no VR Plugs orBPVinstalled. Condition ofCellar Good Condition. I did not observe and excessive water in cellar, trash or any sheen. — Surrounding Surface Condition Everything looked good. I did not see debris or sheen around the pad. - Comments | verified the location using the pad map. NoOA(monobonecomp|etion). — 5upemisor[ommen\s Photos (2)attached -~ Monday, September 2O'ZO2O N M >, N X I � m co m C CV O V Q U CO 0 0- -4 U 3 Qoo m c CD arCn�-0 V O 3 0 F- .0 Cl) Qa_a r.y A rr y%,fr r + 5 a "1 U isZ i ac�i+`S F� •9 Y 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 Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE 8/19/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-56 220-017 CD: HALLIBURTON Geosteering / ADR/DGR Please include current contact information if different from above. Received by the AOGCC 08/19/2020 PTD: 2200170 E-Set: 33674 Abby Bell 08/19/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23669-00-00Well Name/No. MILNE PT UNIT S-56Completion StatusSUSPCompletion Date4/15/2020Permit to Drill2200170Operator Hilcorp Alaska, LLCMD14500TVD4022Current StatusSUSP7/22/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP/DGR/AGR/ABG/ADR/EWR MD and TVDNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF7/20/2020105 14500 Electronic Data Set, Filename: MPU S-56 PB1 LWD Final.las33572EDDigital DataDF7/20/20205355 14462 Electronic Data Set, Filename: MPU S-56 PB1 ADR Quadrants All Curves.las33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final MD.cgm33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final TVD.cgm33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56PB1i Surveys.xlsx33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56PB1_Definitive Survey Report.txt33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56PB1_GIS.txt33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56PB1_Plan.pdf33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56PB1_VSec.pdf33572EDDigital DataDF7/20/2020 Electronic File: MPU S-5PB1_Definitive survey report.pdf33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final MD.emf33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final TVD.emf33572EDDigital DataDF7/20/2020 Electronic File: MPU_S-56PB1_Geosteering.dlis33572EDDigital DataDF7/20/2020 Electronic File: MPU_S_56PB1_Geosteering.ver33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final MD.pdf33572EDDigital DataWednesday, July 22, 2020AOGCCPage 1 of 2PB1MPU S-56 PB1LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23669-00-00Well Name/No. MILNE PT UNIT S-56Completion StatusSUSPCompletion Date4/15/2020Permit to Drill2200170Operator Hilcorp Alaska, LLCMD14500TVD4022Current StatusSUSP7/22/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:4/15/2020Release Date:3/2/2020DF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final TVD.pdf33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final MD.tif33572EDDigital DataDF7/20/2020 Electronic File: MPU S-56 PB1 LWD Final TVD.tif33572EDDigital Data0 0 2200170 MILNE PT UNIT S-56 PB1 LOG HEADERS33572LogLog Header ScansWednesday, July 22, 2020AOGCCPage 2 of 2Well currently suspended. 10-407 submitted for PB1 only.M. Guhl7/22/2020 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 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 7/15/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-56 PB1 AGR ABG DGR EWR ADR MD /TVD CD: HALLIBURTON FINAL ELECTRIC LOGS Please include current contact information if different from above. Received by the AOGCC 07/20/2020 PTD: 2200170 E-Set: 33572 Abby Bell 07/20/2020 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 36.9' BF:36.9' Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 20" X-52 107' 4-1/2" L-80 4,061' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate LONS 01-001 1,971' MD / 1,870' TVD N/AN/A N/A 14,500' MD / 4,022' TVD Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A ROP, DGR, AGR, ABG, ADR, EWR MD & TVD Flow Tubing Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST N/A Date of Test: Per 20 AAC 25.283 (i)(2) attach electronic information 11,086' 4,094' DEPTH SET (MD) N/A PACKER SET (MD/TVD) CASING WT. PER FT.GRADE 13.5# 564366 561675 TOP SETTING DEPTH MD Surface 5,400' SETTING DEPTH TVD 6006986 BOTTOM TOP 236 bbls Surface107' HOLE SIZE AMOUNT PULLED 50-029-23669-00-00 MPU S-56 565478 5999884 1870' FSL, 1657' FEL, Sec 12, T12N, R10E, UM, AK CEMENTING RECORD 5998524 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 3221' FSL, 533' FEL, Sec 12, T12N, R10E, UM, AK 205' FNL, 1007' FWL, Sec 1, T12N, R10E, UM, AK 220-017 / 320-163 Milne Point Field / Schrader Bluff Oil Pool 63.5' 3,320' MD / 2,914' TVD March 29, 2020 March 15, 2020 ADL380109 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 4/15/2020 42" Stg 1 L - 418 sx / T - 418 sx ±270 ft3215.5# Stg 2 L - 136 sx / T - 270 sx 12-1/4" Cementless Injection Liner w/ ICDs (FISH) 3-1/2" SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 8-1/2" TUBING RECORD 4,095' 2,784' 9-5/8" 40# L-80 Surface 5,363' Surface WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 10:48 am, May 07, 2020 Suspension Date 4/15/2020 HEW RBDMS HEW 5/7/2020 liner stuck off bottom gls Susppended DLB 05/07/2020 gls 5/13/20 DSR-5/7/2020 SFD 5/7/2020 G Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 1,971' 1,870' Top of Productive Interval 5,364' (Production Hole) 4,095' 2,527' 2,296' 4,130' 3,579' 4,972' 4,041' 5,255' 4,093' SB NE 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Ugnu LA3 SB NA If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: SB NE FORMATION TESTS Permafrost - Top SV1 This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Wellbore Schematic, Drilling Reports, Definitive Directional Surveys, Csg and Cmt Report, FIT graphs Signature w/Date: No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Cody Dinger DN: cn=Cody Dinger, ou=Users Date: 2020.05.07 10:34:02 - 08'00' Cody Dinger _____________________________________________________________________________________ Revised By: CJD 5/5/20 Schematic Milne Point Unit Well: MPU S-56 PTD: 220-017 API: 50-029-23669-00-00 Depth MD Depth TVD ICD/Swell Packer Detail 5,517’ 4,089’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 6,075’ 4,066’Tendeka Water Swell Packer 6,588’ 4,053’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,020’ 4,061’Tendeka Water Swell Packer 7,452’ 4,064’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,925’ 4,044’Tendeka Water Swell Packer 8,482’ 4,035’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 8,994’ 4,047’Tendeka Water Swell Packer 9,588’ 4,059’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 9,979’ 4,050’Tendeka Water Swell Packer 10,779’ 4,054’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x 34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.679” Surface 5,363’ 0.0758 4-1/2” Liner (FISH) 13.5 / L-80 / Hyd 625 3.795” 5,400’ 11,086’ 0.0149 Tubing Detail 3-1/2” Tubing Kill String 9.3# / L-80 / EUE 8RD 2.867” Surface 2,784’ 0.0087 JEWELRY DETAIL No Top MD Item ID 1 3,320’ Baker K1 CIBP - 2 5,282’ Cement Retainer 3 11,086’ Shoe 3.970” OPEN HOLE / CEMENT DETAIL 42" ±270 ft3 12-1/4" Stg 1 –Lead 418 sx/ Tail 418 sx Stg 2 –Lead 136 sx / Tail 270 sx 8-1/2” 246 sx / 35 bbls below / 15 bbls above Cmt Retainer @ 5,282’ TOC @ ±5,102’ 8-1/2” FISH Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 416’ TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API#: 50-029-23669-00-00 Suspended by Innovation: 4/15/2020 liner stuck off bottom \ retainer Hole in casing from RCT cutterK1 CIBP casing test 2500 psi Activity Date Ops Summary 3/11/2020 PJSM Remove stairs on either side of Sub. Spot and shim Sub over Well. SIMOPS Slick Line operations being performed on S-57.;Spot cat walk. Start spotting Pipe Shed, 2 tires on Rear ODS Axle lost air. Attempt to fill tires. Call for Peak Tire Man. Allow tool service to continue to tie in S-56 while W/O tires.;Check running Gens and air Press on tires. SIMOPS Operations Cont work on S-57 installing Tree, Foundation and flow line.;Operations finished work on S-57. Set Matt boards. Spot Beyond Choke house. Remove hooch's & heaters around tires. Spot Mud Mod and Gem Mod. SIMOPS Set outriggers on Sub. Begin hooking up inner connects.;Daily hauled 0 bbls to G&I total = 0 bbls Daily water hauled 0 bbls from L Pad total = 0 bbls Daily Metal collected 0 lbs total = 0 lbs Daily Fluid lost production 0 bbls total = 0 bbls 3/12/2020 PJSM Cont spotting Gen Mod, Envirovac, Break Shack, cutting box and hot house. SIMOPS Hook up air, H2O and stream. Released Peak at 08:00.;PJSM Run steam around rig. Berm around cutting box area. Work on rig acceptance checklist. Safe out walkways, rooftops, stairways and landings. Begin prep for scoping Derrick up.;PJSM Cont rolling steam around rig. Hook up inner connects. Cont rig acceptance checklist. C/O bad heater cores. Scope up Derrick and bridle down. Hang tongs. Inspect and assemble MP's. Load Pipe Shed W/ BHA components. Rig accepted at 18:00.;PJSM Set Stack on Diverter Tee. Snug bolts on Stack, Tee, DSA and starter Head.;PJSM Install Knife Valve and Diverter. PHASE 2 conditions at 22:00 stop work outside and work at a reduced pace. Keep all trucks staged at Meline Point due to phase conditions.;PJSM TRQ bolts on Stack. Conductor adapter not tightened. Put on 3.125" 1502 on Kill line. Put on 4" Conductor Ball Valves. Complete MP EAM's. Screen up Shakers W/ 100's. Cont. work on Boiler #1 feed pump.;PJSM Hook up chain and binders to Stack. Disconnect Bridge Cranes. Install plug valve and cap on Kill Line. Lock out Mezz Kill and Sub cold start. Install riser and air up boots. Hook up jumper hoses to Bag. Energize Koomey system. Hook up drain hoses to drip pan.;SIMOPS install Mouse hole and close Bag. Install DS Mule in Derrick.;PJSM P/U M/U 5" D.P. 9 stands 5" NC50 D.P. and rack back in Derrick. (Drift OD 3.125");Shut rig operations due to Phase 3 weather conditions. Perform inventories and light duty cleaning around rig.;Daily hauled 0 bbls to G&I total = 0 bbls Daily water hauled 780 bbls from L Pad total = 780 bbls Daily Metal collected 0 lbs total = 0 lbs Daily Fluid lost production 0 bbls total = 0 bbls 3/13/2020 Cont wait on weather Phase 3 weather condition. Light duty cleaning around rig.;Weather went to Phase 2. PJSM P/U M/I 5" D.P. NC50 and rack back in Derrick 43 stands. (Drift OD 3.125") SIMOPS Cont work on Diverter and bring on 290 bbls Spud Mud into Pits.;Cont wait on weather Phase 3 weather condition. Light duty cleaning around rig.;Daily hauled 0 bbls to G&I total = 0 bbls Daily water hauled 0 bbls from L Pad total = 780 bbls Daily Metal collected 0 lbs total = 0 lbs Daily Fluid lost production 0 bbls total = 0 bbls 3/14/2020 Cont wait on weather Phase 3 weather condition. Light duty cleaning around rig.;Phase 2 weather condition. P/U M/U 5" D.P. and rack back in Derrick 10 stands. (Drift OD 3.125");Suspend operations Due to Phase 3 weather. Perform light duty around rig.;Phase 2 weather condition. P/U M/U 5" D.P. and rack back in Derrick 10 stands. (Drift OD 3.125") Crew 4 came to Rig to relieve Crew 1 due to 18 hrs on tour.;Phase 2 weather condition. PJSM Assist NOS setting Slip Lock Head and torquing to 400 ft/lb. Test to 500 PSI. SIMOPS Clean suction manifold. Spot check Divert line flange bolts. Safe out walk ways and steps of snow and ice. At 21:00 Crew 2 C/O Crew 4 due to weather conditions in Deadhorse.;Phase 2 weather conditions. PJSM L/D Mousehole. Bleed down Koomey and install Knife Valve lines. Energize Koomey. P/U BHS Subs and X/O's to rig floor.;PJSM Pull Bushings and add spare air boot to riser. Install 10.25" Bushing inserts. Perform full Derrick inspection and Top Drive. Service Skate. Went to Phase 1 at 01:10.;PJSM Press test HP mud lines to 3,500 PSI.;PJSM Gather up tools and prep for installing Diverter line. Due to clearing of roads and pads crane was unavailable to be on location until 04:00. Start installing Diverter sections and supports W/ Crane.;Daily hauled 0 bbls to G&I total = 0 bbls Daily water hauled 0 bbls from L Pad total = 780 bbls Daily Metal collected 0 lbs total = 0 lbs Daily Fluid lost production 0 bbls total = 0 bbls n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: MP S-56 Milne Point Hilcorp Energy Company Composite Report North Slope Borough, AK Contractor AFE #: AFE $: Innovation Job Name:2010573D MPU S-56 Drilling Spud Date: 3/15/2020 PJSM Finish R/U Diverter line. Trq all Bolts and saddles. Get RKB Annular 11.93', Graound 26.61'. SIMOPS Begin loading and staging MWD tools in Pipe Shed.;PJSM Perform Diverter function test. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. P/U 5" D.P. and set in Annular. Starting Press 3,000 PSI, after closing 1,950 PSI. Annular close time 15 sec. Knife Valve open 4 sec. Nitrogen Avg 6 bottles 2,366 PSI. 200 PSI 14 sec, full 56 sec.;Witness waived by Austin McLeod at 06:53 am.;PJSM Stage all BHA on floor and Pipe Shed. Hold Pre Spud Metting.;PJSM P/U M/U 12.25" K5M633X Hybrid, 8" StrataForce 4:5-5.3 stg mud motor and X/O. Flood lines and fill Stack. Leak on hole fill line valve, repair. Press test Goe Span to 3,500 PSI, good.;PJSM RIH W/ 5" D.P. NC50 19.5# tag bottom at 107' MD. Displace to 8.85 ppg Spud Mud. Drill ahead F/ 107' to 170' MD, 400 GPM, 530 PSI, 40 RPM, TRQ 1.8K, WOB 5K, P/U 45K, SLK 45K, ROT 45K.;PJSM Drill 12.25" Surface F/ 170' to 281' MD. 430 GPM, 600 PSI, 50 RPM, TRQ 1.8K, WOB 5K, P/U 48K, SLK 48K, ROT 48K.;PJSM CBU 2X 430 GPM, 600 PSI, 40 RPM, TRQ 1.8K. POOH on elevators F/ 281' to 33' MD. No issue.;PJSM P/U M/U 8" DGR, 8" EWR-P4, 8" DM, 8" PWD, 8" HCIM, 8" TM, 8" UBHO (94.04'), 2 ea NM FC to 151.78'. Cont RIH W/ 5" HWDP to 281' MD. RFO 280.54°. Downloaded MWD. SIMOPS Hang Gyro Sheave and R/U ELine.;PJSM Drill 12.25" Surface W/ 5" HWDP F/ 281' to 500' MD 475 GPM, 1,175 PSI, 50 RPM, TRQ 2K, WOB 5K, P/U 71K, SLK 58K, ROT 64K. High resistivity seen by MWD starting at ~300' MD.;ROT & Rec CBU F/ 466' to 500' MD 475 GPM, 1,170 PSI, 50 RPM, TRQ 1.5K, P/U 67K, SLK 56K, ROT 64K. Blow down Top Drive. Run Gyro, orient motor and shoot Gyro survey 108' back F/ Bit.. Had issue at surface and C/O Comm Box in ELine Unit.;Slide and Rot F/ 500' to 545' MD. 475 GPM, 1,175 PSI, 50 RPM, TRQ 2K, WOB 16K, R/F 58%, Max Gas 9U, ECD 9.75, P/U 71K, SLK 58K, ROT 64K. Blow down Top Drive. Perform Gyro surveys 108' F/ Bit @ 355', 416', MD to ensure separation from close approach MP-41.;Rotate to Kick at 500’ MD. Gyro Survey: 385’ MD / .94° Inc / 33.95° Az, which indicated we were moving toward MPS-41. Sliding 210° gyro toolface move back vertical and toward planned Azi 185°. Sliding W/ gyro surveys 108’ back f/ bit.;Slide and Rot F/ 545' to 712' MD. 475 GPM, 1,355 PSI, 50 RPM, TRQ 2K, WOB 10-15K, R/F 58%, Max Gas 0U, ECD 9.64, P/U 75K, SLK 75K, ROT 75K. ROT hrs 3.92, SLD hrs 0.64, Blow down Top Drive. Perform Gyro surveys 108' F/ Bit @ 478', 591' & 604' MD to ensure separation from close approach MP-41.;Sliding W/ MWD Gravity toolface F/ 650' MD. Drill to 712’ MD, Gyro survey at 604’ MD 3.65° inc 84.17°. Observed Azi not acting as expected, AC scans utilizing directional projections indicate possible AC issues. Calculated gravity toolface F/ Gyro was done to compare W/ MWD Gravity toolface:;MWD reading High side while Gyro gravity toolface reading 114°. Decision was made to POOH and investigate.;PJSM CBU BROOH F/ 712' to 653' MD. No Issue;POOH on elevators F/ 653' to 154' MD. No issue.;PJSM L/D 2 NM FC. Check tightness of UBHO and scribe down to DGR. Down load MWD. L/D UBHO pulled Pulsar out of TM and L/D TM.;Distance to WP #03: 10.91', 8.80' High, 6.45' Left Daily hauled 285 bbls to G&I total = 285 bbls Daily water hauled 390 bbls from L Pad total = 1,170 bbls Daily Metal collected 0 lbs total = 0 lbs Daily Fluid lost production 0 bbls total = 0 bbls 3/16/2020 PJSM Cont. L/D HCIM, DM, EWR and DGR collars. Check and verify RFO was correct 280.54°. Decision was made to run short BHA. Inspect Bit, good. EWR- P4 had failed down hole.;PJSM P/U M/U new 8" DM & 8" TM to Mud Motor. RFO 263.67°. Plug in and download. P/U M/U UBHO and 2 NM FC.;PJSM RIH BHA #2 W/ 5" HWDP on elevators to 676' MD and wash to 705' MD, no issues. Perform Gyro Survey at 705' MD. Orient Gyro high side to 135° R. Gyro and MWD survey correct. L/D single. P/U 67K, SLK 67K.;Slide and Rot F/ 712' to 801' MD (800' TVD) Total 89' (AROP 44.5'). 475 GPM, 1,385 PSI, 50 RPM, TRQ 2.5K, WOB 10-15K, R/F 58%, Max Gas 0U, ECD 9.6, P/U 76K, SLK 76K, ROT 75K. Blow down Top Drive. Perform Gyro surveys 54' F/ Bit @ 607', 698' & 800' MD;Motor outputs 3-5.5°/100. Closet approach to S-41 9.49' at 604' MD.;Slide and Rot F/ 801' to 1,059' MD (1,056' TVD) Total 258' (AROP 43').. 450 GPM, 1,350 PSI, 50 RPM, TRQ 3.5K, WOB 4-8K, R/F 56%, Max Gas 14U, ECD 9.55, P/U 77K, SLK 75K, ROT 76K. Perform Gyro surveys 54' F/ Bit @ 858', 922', 985' & 1,049' MD.;Slide and Rot F/ 1,059' to 1,472' MD (1,448' TVD) Total 413' (AROP 68.8'). 450 GPM, 1,475 PSI, 50 RPM, TRQ 4.5K, WOB 8-12K, R/F 58%, Max Gas 98U, ECD 9.55, P/U 80K, SLK 76K, ROT 78K. Perform Gyro and Toolface surveys 54' F/ Bit @ 1,113', 1,176', 1,204', 1,303' & 1,367' MD.;Pump through bleeder every other connection. Close approach S-31 46.24' CC @ 1,285' MD. Motor yields F/ 1032' to 1467' MD 7.92°/100' to 4.93°/100'. Magnetic interference MWD to 1,332' MD.;Slide and Rot F/ 1,472' to 1,755' MD (1,698' TVD) Total 283' (AROP 62.8') 475 GPM, 1,525 PSI, 50 RPM, TRQ 5K, WOB 8- 16K, R/F 58%, Max Gas 62U, ECD 9.6, P/U 85K, SLK 80K, ROT 84K. Perform Gyro and Toolface surveys 54' F/ Bit @ 1,430', 1,494', 1,558' & 1,621' MD.;Last Gyro survey at 1,621' MD. Close approach S - 26 39.25' CC @ 1,655' MD. Clean MWD survey at 1,717' MD.;PJSM Perform MWD survey at 1,717' MD no longer need Gyro. CBU 1.5X BROOH F/ 1,755 to 1,694' MD 475 GPM, 1,350 PSI, 50 RPM, TRQ 3K, ECD 9.6, Max Gas 41U. SIMOPS R/D Gyro and Sheave. Monitor well, static.;PJSM BROOH F/ 1,694' to 1,440' MD 450 GPM, 1,335 PSI, 50 RPM, TRQ 2-4K, WOB, R/F 52%, Max Gas 42U, P/U 80K, SLK 78K, ROT 80K.;Distance to WP #04: 4.75', 4.56' Low, 1.34' Right Daily hauled 385 bbls to G&I total = 670 bbls Daily water hauled 390 bbls from L Pad total = 1,560 bbls Daily Metal collected 0 lbs total = 0 lbs Daily Fluid lost production 0 bbls total = 0 bbls 3/17/2020 Cont. to BROOH from 1440' to 1000' at 450 gpm, 1335 psi, 50 rpms, 2000 ft-lbs. PUW 74K, SOW 74K, ROTW 74K.;Blow down top drive. POOH from 1000' to 113'.;L/D BHA: 2 flex collars, UBHO, TM and DM. Remove pulser out of TM. Inspect motor and bit. Clean and clear rig floor.;M/U BHA, : EWR M-5 and DM to motor. Measure RFO (22.22°). M/U TM and UBHO. Plug in and download MWD. Pick up flex collars, XO, HWDP and Jars to 704'. Shallow pulse test MWD.;TIH on elevators from 704' to 1658'. Set down 10K at 957', rotate 1/4 turn and pass by with no further issues. Calculated displacement. Wash down from 1658' to 1755' at 450 gpm, 1180 psi, 30 rpms, 2Kft-lbs. P/U 88K, S/O 82K, ROTW 86K.;Circulate bottoms up at 450 gpm, 1200 psi, 40 rpms, 2Kft-lbs reciprocating pipe.;Cont. drilling 12-1/4 hole F/ 1,755' to 1,912' MD Total 157' (AROP 63') 450 GPM, 1,430 PSI, 50 RPM, TRQ 5K, WOB 10K, Max Gas 92U, ECD 9.85 ppg EMW with 9.2 ppg mud, P/U 90K, SLK 83K, ROT 85K. BROOH to 1721' to ream out 8° dogleg at 1780', down to 7.61°.;Cont. drilling 12-1/4 hole F/ 1,912' to 2,516' MD Total 604' (AROP 110') 500 GPM, 1,680 PSI, 50 RPM, TRQ 4.5K, WOB 3-10K, Max Gas 113U, ECD 10.03 ppg EMW with 9.15 ppg mud, P/U 103K, SLK 87K, ROT 93K. Maintenance slides as needed to maintain WP04 tangent.;Cont. drilling 12-1/4 hole F/ 2,516' to 3,067' MD Total 551' (AROP 110') 540 GPM, 1,990 PSI, 80 RPM, TRQ 6K, WOB 6-16K, Max Gas 93U, ECD 10.03 ppg EMW with 9.1 ppg mud, P/U 110K, SLK 91K, ROT 101K. Maintenance slides as needed. Field wide power loss at 04:20. Swap to Gen power.;Circulate and condition mud 480 gpm, 1460 psi, 80 rpms, 4200 ft-lbs, racking stand back every ~30 -45 minutes due to G&I being down (power outage). Contact Environmental and arrange for supersuckers to dispose at Kuparuk 1B.;Distance to WP #04: 9.28', 1.95' High, 9.07' Right Daily fluid hauled to G&I 684 bbls total = 1,354 bbls Daily water hauled from L Pad Lake 650 bbls total = 2,210 bbls Daily Fluid lost 0 bbls total = 0 bbls PJSM Finish R/U Diverter line. BROOH from 1440' to 1000' at 3/18/2020 Continue to circulate and condition mud at 455 gpm, 1275 psi, 50 rpms, 4000 ft-lbs as supersuckers are re-routed to Kuparuk 1B facility due to field wide power outage shutting down Milne G&I. Rack stand back every 30 minutes to 2802'. PUW 114K, SOW 98K, ROTW 100K. RIH once supersucker offloading;at Kuparuk, from 2802' to 3067' on elevators without issue.;Cont. drilling 12-1/4 hole F/ 3,067' to 3,371' MD Total 304' (AROP 76') 550 GPM, 2,060 PSI, 80 RPM, TRQ 6.5K, WOB 1-10K, Max Gas 23U, ECD 9.96 ppg EMW with 9.0 ppg mud, P/U 120K, SLK 103K, ROT 108K. Primarily sliding for 5°/100 turn and drop as per WP04. Milne G&I online at 12:00.;Cont. drilling 12-1/4 hole F/ 3,371' to 3,755' MD Total 384' (AROP 64') 550 GPM, 1,970 PSI, 80 RPM, TRQ 7.5K, WOB 2K, Max Gas 128U, ECD 9.71 ppg EMW with 9.0 ppg mud, P/U 135K, SLK 100K, ROT 113K. Primarily sliding for 5°/100 directional as per WP04.;Cont. drilling 12-1/4 hole F/ 3,755' to 3,890' MD Total 135' (AROP 39') 550 GPM, 1,985 PSI, 80 RPM, TRQ 9.5K, WOB 5-8K, Max Gas 128U, ECD 9.89 ppg EMW with 9.0 ppg mud, P/U 140K, SLK 100K, ROT 113K. Primarily sliding for 5°/100 directional as per WP04. Observe 400 psi drop in pump pressure.;Trouble shoot pumps. Change out suction and discharge valve and seat on mud pump 1 pod 2.;Cont. drilling 12-1/4 hole F/ 3,890' to 4,0 09' MD Total 119' (AROP 60') 550 GPM, 2,040 PSI, 80 RPM, TRQ 9K, WOB 2K, Max Gas 62U, ECD 9.61 ppg EMW with 9.0 ppg mud, P/U 142K, SLK 100K, ROT 115K. Primarily sliding (65-80%) for 5°/100 directional as per WP04.;Cont. drilling 12-1/4 hole F/ 4,009' to 4,324' MD Total 315' (AROP 57') 550 GPM, 2,050 PSI, 80 RPM, TRQ 9.5K, WOB 2K, Max Gas 540U, ECD 9.68 ppg EMW with 9.0 ppg mud, P/U 148K, SLK 107K, ROT 115K. Primarily sliding (65-80%) for 5°/100 directional as per WP04. Back ream full stands.;Service Rig: change out liner on mud pump #2. Sim Ops grease blocks, wash pipe and top drive. Circulating at 310 gpm, 750 psi, 40 rpms, 7.5K ft-lbs reciprocating pipe.;Distance to WP #04: 21.19', 19.59' High, 8.08' right Daily fluid hauled to G&I 795 bbls total = 2,149 bbls Daily fluid hauled to Kup 1B 228 total = 228 bb;s Daily water hauled from L Pad Lake 1,300 bbls total = 3,510 bbls Daily Fluid lost 0 bbls total = 0 bbls 3/19/2020 Continue changing out liner and wear plate on mud pump 2.;Cont. drilling 12-1/4 hole F/ 4,324' to 4,600' MD Total 276' (AROP 55') 550 GPM, 2,150 PSI, 80 RPM, TRQ 10.5K, WOB 5-15K, Max Gas 507U, ECD 9.63 ppg EMW with 9.0 ppg mud, P/U 156K, SLK 103K, ROT 123K. Primarily sliding (65-80%) for 5°/100 directional as per WP04. Back ream full stands.;At 4466' packed off and stalled out top drive. Increase limiter to 15K to break free. CBU. No increase in cuttings.;Cont. drilling 12-1/4 hole F/ 4,600' to 4,963' MD Total 363' (AROP 49') 550 GPM, 2,120 PSI, 80 RPM, TRQ 11.5K, WOB 10K, Max Gas 840U, ECD 9.61 ppg EMW with 9.0 ppg mud, P/U 160K, SLK 100K, ROT 120K. Primarily sliding (65-80%) for 5°/100 directional as per WP04. Back ream full stands. BROOH to;4836' to ream 9°/100 dogleg. Wash and ream back to bottom.;Cont. drilling 12-1/4 hole F/ 4,963' to 5,122' MD Total 159' (AROP 35') 550 GPM, 2,030 PSI, 80 RPM, TRQ 12.5K, WOB 10K, Max Gas 840U, ECD 9.65 ppg EMW with 9.0 ppg mud, P/U 160K, SLK 98K, ROT 122K. Primarily sliding (65- 80%) for 5°/100 directional as per WP04. Back ream full stands.;Cont. drilling 12-1/4 hole F/ 5,122' to 5,373' MD (casing pt) Total 251' (AROP 56') 550 GPM, 2,057 PSI, 80 RPM, TRQ 12.5K, WOB 5-15K, Max Gas 1182U, ECD 9.61 ppg EMW with 9.0 ppg mud, P/U 158K, SLK 98K, ROT 119K. Primarily sliding (65- 80%) for 5°/100 directional as per WP04.;BROOH to above NE sands (5255') to 5217'. Circulate hole clean, racking stand back every 30 minutes at 550 gpm, 1840 psi, 60 rpms, 11.5K ft-lbs. Max gas 461U.;Distance to WP #04: 21.20', 11.85' Low, 17.58' Left Daily fluid hauled to G&I 1,316 bbls total = 3,465 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bb;s Daily water hauled from L Pad Lake 910 bbls total = 4,420 bbls Daily Fluid lost 0 bbls total = 0 bbls 3/20/2020 Cont. circulating 3 x BU racking stands back every bottoms up. 550 gpm, 1840 psi, 60 rpms, 10-13Kft-lbs, Max gas 463U. ECD 9.6 ppg with 9.0 ppg mud. PUW 159K, SOW 97K, ROTW 124K. Monitor well, static. Wash and ream to 5573' (casing point) with no issues.;BROOH from 5373' to 3755' at 550 gpm, 1630 psi, 80rpms, 6-8K ft-lbs. Max gas 250U, ECD 9.82 ppg. PUW 150K, SOW 102K, ROTW 120K.;BROOH from 3755' to 1976' at 550 gpm, 1430 psi, 80 rpms, 4- 6Kft-lbs, max gas 205U, ECD 9.62 ppg. PUW 100K, SOW 84K, ROTW 90K. Pulling speed 15-25 fpm as hole dictates. Slow pulling speed from 2167' to 2103' and circulate bottoms up prior to permafrost.;Cont. to BROOH from 1976' to 1200' at 550 gpm, 1300 psi, 80 rpms, 5-7K ft-lbs, pulling 10-20 fpm as hole dictates. Pull last two stands slow circulating 2 x BU.;Attempt to POOH on elevators from 1200', rack two stands back and pull tight at 1043' (30K). Slack off and establish rotary and circulation. Continue BROOH from 1043' to 704' at 60-80 rpms with erratic torque 4-9Kft-lbs, 450 gpm, 980 psi.;Attempt to POOH at 704', dragging up to 15K over on first stand. BROOH from 704' to 446' at 40 rpms, 1-4Kft-lbs, 450 gpm, 900 psi. POOH on elevators from 446' to 349' with no issues.;POOH from 349' to surface. Rack back HWDP and Jars. L/D drill collars. Plug in and download. Cont. to L/D BHA. Bit grade 1-1-CT-S-E-I-NO- TD.;Clean and clear rig floor of BHA components. R/D 5" elevators.;Rig up to RIH with casing. Rig up Volant tool, bail extensions, elevators, double stack tongs.;Service rig, grease crown and blocks.;PJSM. P/U shoe joint, check double stack tongs and adjust.;Daily fluid hauled to G&I 684 bbls total = 4,149 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bb;s Daily water hauled from L Pad Lake 910 bbls total = 5,330 bbls Daily Fluid lost 0 bbls total = 0 bbls 3/21/2020 Continue to M/U and Bakerlok shoe track. Check floats - good. RIH with 9-5/8", 40", L-80 TXP casing to 2296', M/U TQ 21Kft-lbs. PUW 148K, SOW 90K.;Circulate bottoms up staging pumps up to 6 bpm, reciprocating pipe.;Cont. to RIH with 9-5/8" casing from 2296' to 3164'.;Circulate bottoms up staging pumps up to 6 bpm, reciprocating pipe, 0-5 rpms, 10Kft-lbs.;Cont. to RIH with 9-5/8" casing from 3164' to 5,363' (casing point). PUW 245K, SOW 115K. 20 bbls lost while RIH.;Circulate 2 x bottoms up staging pumps up to 7 bpm, 160 psi, reciprocating pipe, Max gas 44U. Establish rotary with TQ limiter set at 15Kft-lbs, 0- 3 rpms while reciprocating.;Monitor well for 30 minutes - static.;Circulate hole at 7 bpm, 160 psi while removing diverter section for cementers to stage unit. Maintain continuous communication with hands. Re-install diverter section.;Continue circulating hole and conditioning mud while rigging up cementers. 7bpm, 125 psi, 1-3 rpms, 15Kft-lbs (TQ limiter set) PUW 240K, SOW 115K. B/D to cementers, and check all equipment. Rig up cement line, cont. circulating 7 bpm, 494 psi through cement line.;Perform 1st stage cement job as per detail. HES pump: 5 bbls and PT lines 1000/4000 psi - good. Pump 57 bbls tuned spacer at 4 bpm, 180 psi Drop bypass plug Pump 175 bbls of 12.0 ppg Type I/II lead cement at 5 bpm, 375 psi Pump 86 bbls of 15.8 ppg Class G tail cement at 4 bpm, 600 psi.;Drop closing plug. Displace with 20 bbls water at 6 bpm, 380 psi, 205.5 bbls 9.3 ppg Spud mud at 7 bpm 380 psi, 80 bbls tuned spacer (10 below ES cementer, 70 above) at 380 psi, followed by 90.4 bbls (2 bbls early) of 9.3 ppg spud mud at 7 bpm, slow rate with 10 bbls to go to 3 bpm, FCP 710 psi.;bump plug and pressure up to 1215 psi and hold for five minutes. Check floats - good bled back 1.5 bbls. Rotate at 0-3 rpms, 15Kft-lbs and reciprocate throughout job until 90 bbls left into displacement, pipe would not break over. No losses during job. CIP at 04:43.;Pressure up at 3 bpm and open ES cementer at 2712 psi. Circulate through ES cementer staging up to 7 bpm, 545 psi. All spacer returned to surface contaminated with ~15 bbls of cement.;Daily fluid hauled to G&I 279 bbls total = 4,428 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 260 bbls total = 5,590 bbls Daily Fluid lost 37 bbls total = 37 bbls 1st Stage ;Cont. drilling 12-1/4 hole F/ 4,324' to 4,600' MD RIH with 9-5/8", 40", L-80 TXP casing to 2296', M/U TQ 21Kft-lbs. P )qp gp gp ;Perform 1st stage cement job as per detail. HES pump: 5 bbls and PT lines 1000/4000 psi - good. Pump 57 bbls tuned spacer at 4pggjp pp pg pp bpm, 180 psi Drop bypass plug Pump 175 bbls of 12.0 ppg Type I/II lead cement at 5 bpm, 375 psi Pump 86 bbls of 15.8 ppg Class G tail cement at 4 bpm, 600p p p yp p g p ppg yp ppp ppg p psi.;Drop closing plug. Displace with 20 bbls water at 6 bpm, 380 psi, 205.5 bbls 9.3 ppg Spud mud at 7 bpm 380 psi, 80 bbls tuned spacer (10 below ES ppgpgp p p ppg p p p p( cementer, 70 above) at 380 psi, followed by 90.4 bbls (2 bbls early) of 9.3 ppg spud mud at 7 bpm, slow rate with 10 bbls to go to 3 bpm, FCP 710 psi.;bump )p y (y) ppg p p plug and pressure up to 1215 psi and hold for five minutes. Check floats - good bled back 1.5 bbls. Run Surface casing 95/8" 3/22/2020 Cont. circulating 3 x BU at 6 bpm, 350 psi. prepping for second stage cement job. shut down pumps. B/D cement line. Disconnect knife valve. Flush stack x 2: Fill stack and function bag x3. Establish circulation and stage pumps up to 5 bpm, 397 psi.;Hole packed off, attempt to regain circulation. Stretch pipe and stage pressure up to 2000 - 2750 psi multiple times and bleeding off until circulation was established at 3 bpm, 250 psi. Stage up to 6.5 bpm, 1000 psi. Circulate hole clean observe pressure drop to 615 psi with;cement contaminated mud at surface.;Cont. circulating hole clean at 6.5 bpm, 535 psi while prepping for second stage cement job. Break out of Volant tool and re-engage.;Perform 2nd stage cement job. HES pumped: 5 bbls water at 4 bpm, 225 psi 50 bbls 10.0 ppg tuned spacer with 0.5 ppg Poly-E-Flake and 4# red dye at 5 bpm, 340 psi 107 bbls 10.7 ppg Perm 'L' Lead cement at 5 bpm, 380 psi 241 bbls 10.7 ArcticCem Lead cement at 5 bpm, 450 psi.;Observe green cement at surface 224 bbls into ArcticCem cement Pump 56 bbls 15.8 ppg Class G tail cement Drop closing plug HES Displace with 20 bbls water at 6 bpm 392 psi, swap to rig pumps with 140 bbls of 9.15 at 6 bpm, 770 psi. Slow to 3 bpm with 10 bbls to go, FCP 550 psi.;Bump plug 3 bbls early. Pressure up to 2000 psi, observing ES cementer shifting close at 1566 psi. Hold pressure for 5 minutes and bleed back 1.9 bbls - confirm tool closed. CIP at 21:59 236 bbls of green lead cement returned to surface. No losses during job.;Pump through cement line with black water and blow down. Flush flow line. Drain stack and soak with black water. Rig down Volant tool, install casing elevators.;Flush stack x 2, drain and re-fill with black water. Disconnect knife valve from accumulator. Function bag x 3. Install casing elevators, clean out 9-5/8" joint to be cut. Remove mousehole, remove chain binders from stack and hook up bridge cranes. Rig down diverter 'T'. Unbolt from BOP from;starting head and raise stack. SimOps: Begin cleaning pits, rig down remaining diverter line.;Center casing. Install casing slips and set 125K on slips. Prep and cut 29.24' off casing. Remove casing elevators, install 5" elevators. SimOps: Continue cleaning pits, load pipe shed with 5" drill pipe.;Set stack down and hot bolt. Johnny wack stack with black water. Blow down top drive. Remove knife valve from diverter 'T'. SimOps: continue cleaning pits. Load pipe shed with 5" drill pipe.;Daily fluid hauled to G&I 1,334 bbls total = 5,762 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 910 bbls total = 6,500 bbls Daily Fluid lost 0 bbls total = 37 bbls 3/23/2020 Cont to remove knife valve from diverter 'T', pull riser, set stack on pedestal. Pull starting head. SimOps: Continue cleaning pits. Bring test plug, wear ring to rig floor.;Clean cellar box. Remove 4" conductor valves and install caps. Dress up casing cut as per wellhead rep. Install T103 adapter and test to 2475 psi for 10 minutes - good. Install wellhead and test void 500 psi/5 min, 5000 psi/10 min. SimOps: PM on Mud pumps.;Install test plug. Install and orientate DSA and 2' spacer spool. N/U BOP: check measurement for riser. Hook up choke and kill lines, tighten all flange bolts. Install riser. Obtain RKB's. SimOps: Continue with PM on mud pumps, continue cleaning pits.;Rig up to test BOPE. M/U dart valve, TIW, and 1502 side entry. P/U test joint. Flood lines, purge air.;Test BOPE 5" and 3.5" test joints, 250/3000 psi as per PTD. AOGCC's right to witness waived by Jeff Jones. LPR's failed on low test. Function and trouble shoot.;Bleed accumulator pressure. Open LPR doors, redress LPR's with top and body seals. Re-install LPR's and break in as per procedure functioning x 5.;Cont. to Test BOPE 5" and 3.5" test joints, 250/3000 psi as per PTD. AOGCC's right to witness waived by Jeff Jones. no additional failures. Accumulator drawdown: starting pressure 3000 psi, final 1550 psi; first 200 psi recharge 28 seconds, final 99 seconds. (6) N2 bottles with 2358 psi average.;Rig down and L/D testing equipment. Blow down TD, choke and kill lines/manifold. Install hydraulic elevators. Pull test plug, set wear bushing.;Daily fluid hauled to G&I 644 bbls total = 6,406 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 520 bbls total = 7,020 bbls Daily Fluid lost 0 bbls total = 37 bbls 3/24/2020 M/U 8.5" drill out assembly. M/U bit to mud motor. RIH with HWDP and Jars to 592'.;Drift (3.125"), pick up and single in the hole with 5" drill pipe from 597' to 2120'. PUW 88K, SOW 73K.;Wash and ream down from 2120' to 2133', tag cement with 3K. Drill cement and ES cementer(2142', on depth) to 2,149' at 7.5 bpm, 420 psi, 40 rpms, 4.5Kft-lbs. Work through several times with no issues. rack stand back to 2120'.;Continue to drift (3.125") pick up and single in the hole from 2120' to 5044'. PUW 160K, SOW 76K. RIH from derrick from 5044' to 5,222' tag cement with 5K. P/U and establish circulation, wash down and confirm tag. Rack one stand back to 5,171'.;Cut and slip 94' of drilling line. Check brakes - within specs. Circulating bottoms up at 2 bpm, 50 psi. Service rig: grease/inspect crown, blocks, top drive, drawworks and iron roughneck.;Blow down top dirve. Rig up and test casing to 2500 psi for 30 minutes - good test. Pumped 4.5 bbls, bled back 4.3 bbls. R/D testing equipment.;Wash down from 5171' to 5,222'. Drill cement, shoe track and 20' of new hole to 5,793'. All shoe track equipment tagged on depth. 500 gpm, 875 psi, 50 rpms, 12-15Kft-lbs. PUW 165K, SOW 76K, ROTW 115K.;Displace to 8.9 ppg Baradril-N: pump high viscosity sweep followed by new mud. Circulate additional bottoms up ensuring even MW. 450 gpm, 570 psi, 70 rpms, 11-13Kft-lbs. Reciprocating pipe.;Obtain SPR's. Rack one stand back to 5358'. Monitor well, static. Blow down TDS. Rig up test equipment. Flood lines and purge air Perform FIT to 12.0 ppg EMW - good test. Pump 1.1 bbls and bled back 0.7 bbls. Rig down testing equipment, blow down top drive.;POOH on elevators from 5359' to 5044' - no indication of swabbing. Monitor well, static. Pump dry job. B/D top drive, install stripping rubber, air slips. Cont. POOH on elevators to 592'. Calculated displacement observed. PUW 60 SOW 60.;L/D 10 joints HWDP, rack back jar/HWDP stand. L/D 4 joints of HWDP. L/D motor and bit. Bit grade 1-1-WT-A-I-E-NO-BHA;Daily fluid hauled to G&I 659 bbls total = 7,065 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 130 bbls total = 7,150 bbls Daily Fluid lost 0 bbls total = 37 bbls 3/25/2020 Clean and clear rig floor, bring TM and DM collars to rig floor.;M/U BHA: NOV PDC bit, Geo-pilot, ADR/HCIM collar, ILS, DGR collar, PWD collar, DM collar, TM collar and float sub. Plug in and upload.;Service rig: grease crown, top drive and blocks.;Pipe skate would not power up. Troubleshoot pipe skate and reset main breaker switch.;Cont. to M/U BHA M/U (3) flex collars, float sub, (2) HWDP, SLB Jars, and HWDP to 306'.;Pick up, drift (3.125"), and single in the hole with 5" drill pipe from 306' to 4,885'. Fill pipe and break in Geo-Pilot at 2,535'.;RIH out of derrick from 4,885' to 5,330'. Fill pipe and obtain parameters: PUW 146K, SOW 76K, ROTW 110K. Wash last stand to 5393' with no issues. Obtain SPR's.;Drill 8.5" production lateral F/ 5393' - T/ 5839' (446' total, 99fph AROP). WOB 5K, 550 gpm, 1530 psi, 120 rpm, 13k tq on, 9.79 ECD's with 8.9 ppg MW. Max Gas = 1888U. P/U 165K, S/O 74K, ROT 107K.;Drill 8.5" production lateral F/ 5839' - T/ 6412' (573' total, 96 fph AROP). WOB 10K, 550 gpm, 1650 psi, 120 rpm, 13k tq on, 10.19 ECD's with 8.9 ppg MW. Max Gas = 1055U. P/U 157K, S/O 77K, ROT 110K. Backream 20' every stand.;No faults have been crossed so far this lateral. 6 concretions have been drilled so far for a total footage of 16' (1.6% of the lateral). 984' drilled in NE-Sands Distance to WP 05: 1.02', 0.75' High, 0.69' Left;Daily fluid hauled to G&I 114 bbls total = 7,179 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 260 bbls total = 7,410 bbls Daily Fluid lost 0 bbls total production = 0 bbls Fluid lost surface hole 37 bbls. FIT g pp pppg ;Perform 2nd stage cement job. HES pumped: 5 bbls water at 4 bpm, 225 psi 50 bbls 10.0 gj gg g jpp pp ppg tuned spacer with 0.5 ppg Poly-E-Flake and 4# red dye at 5 bpm, 340 psi 107 bbls 10.7 ppg Perm 'L' Lead cement at 5 bpm, 380 psi 241 bbls 10.7ppg p ppg y y p p ppg p p ArcticCem Lead cement at 5 bpm, 450 psi.;Observe green cement at surface 224 bbls into ArcticCem cement Pump 56 bbls 15.8 ppg Class G tail cement Droppp g pppg closing plug HES Displace with 20 bbls water at 6 bpm 392 psi, swap to rig pumps with 140 bbls of 9.15 at 6 bpm, 770 psi. Slow to 3 bpm with 10 bbls to go, wgp g p p p pgpp p p pg FCP 550 psi.;Bump plug 3 bbls early. Pressure up to 2000 psi,observing ES cementer shifting close at 1566 psi. Hold pressure for 5 minutes and bleed back pppg y p p ggpp 1.9 bbls - confirm tool closed. CIP at 21:59 236 bbls of green lead cement returned to surface. No losses during job.;Pump through cement line with black water 2nd Stage pgpp Perform FIT to 12.0 ppg EMW y . 984' drilled in NE-Sands BOPE test pp py BOPE 5" and 3.5" test joints, 250/3000 psi as per PTD. AOGCC's right to witness waived by Jeff Jones. 3/26/2020 Drill 8.5" lateral F/ 6412' - T/ 6728' (316' total, 126 fph AROP). WOB 10K, 550 gpm, 1736 psi, 110 rpm, 13-14k tq on, 10.42 ECD's with 9.0 ppg MW. Max Gas = 1105U. P/U 163K, S/O 76K, ROT 108K. Backream 20' every stand.;Change out wear plate, swab, and gaskets on MP#1 pod#1.;Drill 8.5" lateral F/ 6728' - T/ 6985' (257' total, 128 fph AROP). WOB 10K, 550 gpm, 1700 psi, 120 rpm, 13k tq on, 10.33 ECD's with 9.0 ppg MW. Max Gas = 538U. P/U 154K, S/O 78K, ROT 106K. Backream 20' every stand.;Drill 8.5" lateral F/ 6985' - T/ 7558' (573' total, 96 fph AROP). WOB 10K, 450 gpm, 1440 psi, 100 rpm, 15-17k tq on, 10.48 ECD's with 9.0 ppg MW. Max Gas = 385U. P/U 152K, S/O 71K, ROT 106K. Backream 20' every stand.;Drill 8.5" lateral F/ 7558' - T/ 8320' (762' total, 127 fph AROP). WOB 12-15K, 550 gpm, 2000 psi, 100 rpm, 15-16k tq on, 10.97 ECD's with 9.0 ppg MW. Max Gas = 700U. P/U 158K, S/O 66K, ROT 105K. Backream 20' every stand.;Drill 8.5" lateral F/ 8320' - T/ 8891' (571' total, 95 fph AROP). WOB 10K, 550 gpm, 1975 psi, 110 rpm, 16-17k tq on, 10.74 ECD's with 9.0 ppg MW. Max Gas = 1040U. P/U 174K, ROT 104K, lost slackoff at 8891'. Backream 20' every stand. Exited top of NE-sands at 8331', re-entered NE- sands at 8391'.;No faults have been crossed so far this lateral. 16 concretions have been drilled so far for a total footage of 82' (2.4% of the lateral). Total footage in NE Sand = 3402', out of NE = 60' Distance to WP#05: 15.98', 12.1' High, 10.43' Left.;Daily fluid hauled to G&I 987 bbls total = 8,166 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 910 bbls total = 8,320 bbls Daily Fluid lost 0 bbls total production = 0 bbls Fluid lost surface hole 37 bbls. 3/27/2020 Drill 8.5" lateral F/ 8891' - T/ 9528' (637' total, 106 fph AROP). WOB 10-14K, 550 gpm, 2077 psi, 130 rpm, 18k tq on, 11.02 ECD's with 9.0 ppg MW. Max Gas = 553U. P/U 190K, S/O N/A, ROT 105K. Backream full stand.;Drill 8.5" lateral F/ 9528' - T/ 10,100' (572' total, 95 fph AROP). WOB 10-14K, 550 gpm, 2125 psi, 120 rpm, 18k tq on, 10.96 ECD's with 9.0 ppg MW. Max Gas = 785U. P/U 205K, S/O N/A, ROT 107K. Backream full stand.;Drill 8.5" lateral F/ 10,100' - T/ 10,799' (699' total, 116 fph AROP). WOB 12K, 550 gpm, 2140 psi, 100 rpm, 18k tq on, 11.08 ECD's with 9.1 ppg MW. Max Gas = 1254U. P/U 215K, S/O N/A, ROT 106K. Backream full stand.;Drill 8.5" lateral F/ 10,799' - T/ 11,372' (573' total, 96 fph AROP). WOB 15K, 550 gpm, 2165 psi, 100 -110 rpm, 20.5k tq on, 11.04 ECD's with 9.0 ppg MW. Max Gas = 1527U. P/U 226K, S/O N/A, ROT 106K. Backream 30' per stand.;No faults have been crossed so far this lateral. 30 concretions have been drilled so far for a total footage of 171' (2.9% of the lateral). Total footage in NE-sands 5,867', Total footage out of zone 60' Distance to WP05: 3.82', 1.93' High, 3.3' Left.;Daily fluid hauled to G&I 1,401 bbls total = 9,567 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 1300 bbls total = 9,620 bbls Daily Fluid lost 0 bbls total production = 0 bbls Fluid lost surface hole 37 bbls. 3/28/2020 Drill 8.5" lateral F/ 11,372' - T/ 12,134' (762' total, 127 fph AROP). WOB 13K, 550 gpm, 2330 psi, 110 rpm, 22k tq on, 11.39 ECD's with 9.15 ppg MW. Max Gas = 7967U. P/U 230K, S/O N/A, ROT 103K. Backream full stands. SPR's at 12,131' 32/48 strokes: MP1 290/365, MP2 288/370 psi.;Drill 8.5" lateral F/ 12,134' - T/ 12,959' (825' total, 138 fph AROP). WOB 16-18K, 550 gpm, 2400 psi, 100 rpm, 23k tq on, 11.51 ECD's with 9.15 ppg MW. Max Gas = 1302U. P/U 230K, S/O N/A, ROT 102K. Backream full stands. SPR's at 12,639' 32/48 strokes: MP1 305/380, MP2 300/375 psi.;Exited top of NE sands at 12,797 and re-entered at 12,918'.;Drill 8.5" lateral F/ 12,959' - T/ 13,214' (255' total, 46 fph AROP). WOB 11-14K, 550 gpm, 2350 psi, 100 rpm, 22k tq on, 11.43 ECD's with 9.15 ppg MW. Max Gas=865U. P/U 228K, S/O N/A, ROT 104K. Backream full stands. A concretion was encountered at 13,183' with initial ABI's indicated at 12.26°.;DLS over 4' and 6.8° DLS over 13'. Pick up and with Geo-pilot at home ream down with the assembly taking weight as it worked through concretion up to 22K. Ream x2 with ABI showing a 3.77°DLS over 10'.;Change out seals on liner and inspect wear plate, MP 1 Pod 1. Work pipe circulating 300 gpm, 1000 psi, 100 rpms, 20-22Kft-lbs.;Drill 8.5" lateral F/ 13,214' - T/ 13,760' (546' total, 91 fph AROP). WOB 15K, 550 gpm, 2460 psi, 110 rpm, 25k tq on, 11.74 ECD's with 9.15 ppg MW. Max Gas = 591U. P/U 242K, S/O N/A, ROT 100K. Backream full stands. SPR's at 13720' at 32/48 MP1 428/508 MP2 430/514.;No faults have been crossed so far this lateral. 40 concretions have been drilled so far for a total footage of 202' (2.4% of the lateral). Total footage in NE-sands 8113', Total footage out of zone 181' Distance to WP05: 24.54', 24.38' High, 2.75' Left.;Daily fluid hauled to G&I 1,373 bbls total = 10,940 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 1430 bbls total = 11,050 bbls Daily Fluid lost 0 bbls total production = 0 bbls Fluid lost surface hole 37 bbls. 3/29/2020 Drill 8.5" lateral F/ 13,760' - T/ 14,359' (599' total, 100 fph AROP). WOB 15K, 550 gpm, 2520 psi, 90 rpm, 25.5k tq on, 11.8 ECD's with 9.15 ppg MW. Max Gas = 661u. P/U 248K, S/O N/A, ROT 101K. Backream full stands.;Drill 8.5" lateral F/ 14,359' - T/ TD 14,500' MD / 4021' TVD (141' total, 94 fph AROP). WOB 15K, 550 gpm, 2520 psi, 90 rpm, 25.5k tq on, 11.7 ECD's with 9.15 ppg MW. Max Gas = 956u. P/U 250K, S/O N/A, ROT 101K. Backream full stands.;Saw moderate stick slip on surface w/ higher than expected torque throughout lateral. Attempted to cleanup vibration with parameters and increased lube % from 3 to 4. No change. Continually backed rpm's down from 120 at start of lateral to 90 final due to high tq (~26k @ TD w/ 4% lubes).;Pump tandem low wt/vis and high wt/vis sweeps (25% increase) and CBU x 4 racking stand back after every BU once sweep out of the hole. 550 gpm, 1400 psi, 90 rpm, 24Kft-lbs, ECD 11.35 ppg with 9.1 ppg mud. max gas 75U.;Wash and ream from 14,327' to 14,500' (TD), 125 gpm, 425 psi, 30 rpms, 16Kft-lbs. PUW 250K, SOW N/A, ROTW 100K.;Monitor well prior to displacing initial 8 bph flow slowing to 3.5 bph after 10 minutes. Pump SAPP train: 3 x 40 bbls SAPP pill followed by 25 bbls Quickdril followed by displacing to 9.2 ppg Quickdrill at 550 gpm, 2400 psi, 90 rpms, 22Kft-lbs reciprocating pipe.;Obtain SPRS: 32/48 MP 1 250/315, MP2 250/310. Monitor well, slight flow continually diminishing from 3.5 bph to 1.79 bph after 20 minutes. Drop 2.39" OD metal drift (no wire).;BROOH from 14,500' to 14,041' laying down single at 475 gpm, 1625 psi, 120 rpms, 23Kft-lbs. Max gas 152U ECD 10.76 ppg with 9.2 ppg quickdril. PUW 255K, SOW N/A, ROTW 100K.;Cont. to BROOH from 14,041 to 12,515' at 475 gpm, 1600psi, 100-110 rpms, 22Kft-lbs. Max gas 518U, ECD 10.76 ppg with 9.2 ppg quickdrill. PUW 245, SOW N/A, ROTW 110. Pull 15-20 fpm as hole allows. Observe excess vibration particularly on surface, increase lube;concentration from 1.5% to 2.5% with no effect. Observe shakers blinding off with sand at 13850', slow pulling speed and pump rate for 2 stands while CBU, slow rate to 425 gpm still blinding off. Screen 2 screens on shaker 1 up to prevent blinding with no effect. Screen down 2 screens to 170's.;No faults were crossed in this lateral. 42 concretions were drilled in this lateral for a total footage of 229' (2.5% of the lateral). Total footage drilled in NE sands 8,956', total footage out of zone 181' Distance to WP 05: 41.82', 41.78' High, 1.86' Right.;Daily fluid hauled to G&I 2,912 bbls total = 13,852 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily water hauled from L Pad Lake 910 bbls total = 11,960 bbls Daily Fluid lost 0 bbls total production = 0 bbls Fluid lost surface hole 37 bbls. Drill 8.5" lateral F/ 13,760' - T/ 14,359' Drill 8.5" lateral F/ 8891' - T/ 9528' Drill 8.5" lateral F/ 11,372' wire).;BROOH from 14,500' to 14,041' Drill 8.5" lateral F/ 6412' - T/ 6728' (316' 3/30/2020 Cont. to BROOH from 12,515' to 10,672' at 480 gpm, 1651 psi, 90 rpms, 17Kft-lbs. Max gas 624U, ECD 10.67 ppg EMW with 9.2 ppg mud. PUW 195K, SOW 60K, ROTW103. Pulling speed 5-15 fpm as hole dictates. Rotary limited by excessive surface vibration/rattle.;Cont. to BROOH from 10,672' to 8,480' at 480 gpm, 1380 psi, 70 rpms, 13Kft-lbs. Max gas 366U, ECD 10.2 ppg EMW with 9.2 ppg mud. PUW 164K, SOW 86K, ROTW103. Pulling speed 10-25 fpm as hole dictates with excessive tq or slight packoffs. Rotary limited by excessive surface vibration/rattle.;Cont. to BROOH from 8,480' to 6,858' at 480 gpm, 1330 psi, 90 rpms, 13Kft-lbs. Max gas 925U, ECD 10.5 ppg EMW with 9.2 ppg mud. PUW 167K, SOW 75K, ROTW105. Pulling speed 5-15 fpm as hole dictates. Rotary limited by excessive surface vibration/rattle.;Cont. to BROOH from 6,858' to 5,585' at 500gpm, 1470 psi, 60-90 rpms, 10Kft-lbs. Max gas 700U, ECD 10.13 ppg EMW with 9.2 ppg mud. PUW 155K, SOW 89K, ROTW110. Pulling speed 5-15 fpm as hole dictates, observing erratic torque and slight packoffs. Rotary limited by excessive surface vibration/rattle.;Daily fluid hauled to G&I 627 bbls total = 14,479 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily metal recovered 4 lbs, total =19 lbs Daily water hauled from L Pad Lake 780 bbls total = 12,740 bbls Daily Fluid lost 0 bbls total production = 0 bbls Fluid lost surface hole 37 bbls. 3/31/2020 Circulate 3x btms up while pulling slow up into shoe F/ 5585' - T/ 5330' MD. Reduced Rpms from 90 to 40 while bringing smart tools thru shoe. Pulled clean. 550 gpm, 1610 psi, 54% flow, 60rpm, 9k tq, 154k up, 115k rot, 95k dn. 531u Max gas w/ 30u BGG. Pump tandem sweep w/ 100% inc/on time.;Circulated first 2x btms up w/ 2x200,2x170's on both shakers. Screened up to 200's on both shakers for last btms up. Mud in/out passed PST (250 coupon).;B/D TDS. Svc rig and monitor well (static). Grease crown, traveling equipment, wash pipe and IR.;PJSM, Pump dry job. B/D TDS & Geo Span. Install Hydraulic elevators, air slips w/ stripping rubber. POOH laying down 5" NC50 drill pipe F/ 5330' - T/ 306' (BHA). 8.6 bbl loss for total trip. Monitor well (1 bph static loss rate). Pull air slips, stripping rubber.;PJSM, L/D 5" HWDP, Jars, NM Flex DC's. Download MWD. Continue L/D smart tools. No damage observed on BHA. B/O bit, bit sleeve and L/D geo-pilot. Bit Grade - 1,1,CT,C,X,I,NO,TD.;PJSM C/O Elevators to 4.5". Stage 216 ea 7.5" OD Centralizers and stop rings. R/U Weatherford Tongs and Equip. Static loss rate ~1 bph.;PJSM P/U Non Ported Shoe and RIH W/ 4.5" 13.5# L-80 W625 Liner to 1,506' MD. Install Centralizers and stop rings every Jnt. Place ICD's and Swell Packers as per tally. Trq W625 to 9,600 ft/lb. Top off every 10 jnts W/ passing PSD Quickdril. P/U 48K, SLK 50K.;PJSM Cont RIH W/ 4.5" 13.5# L-80 W625 Liner to F/ 1,506' to 5,984' MD. Install Centralizers and stop rings every Jnt. Place ICD's and Swell Packers as per tally. Trq W625 to 9,600 ft/lb. Top off every 10 jnts W/ passing PSD Quickdril. P/U 92K, SLK 71K. No losses.;Daily fluid hauled to G&I 228 bbls total = 14,707 bbls Daily fluid hauled to Kup 1B 0 bbls total = 228 bbls Daily metal recovered 5 lbs, total =24 lbs Daily water hauled from L Pad Lake 260 bbls total = 13,000 bbls Daily Fluid lost 13 bbls total production = 13 bbls Fluid lost surface hole 37 bbls. 4/1/2020 Continue run 4.5" Hydril 625, 13.5#, L-80 liner F/ 6079' - T/ 8895' MD. Run injection liner as per tally installing stop ring and solid straight blade centralizer every jt. 110k up, 56k dn. 9.6k tq on connections. Fill on the fly with PST passing clean lubricated brine every 10 jts.;Service rig. Reciprocate pipe slowly while changing failed hydraulic hose on pipe skate. Secure skate, c/o hose and function test (test good).;Continue run 4.5" Hydril 625, 13.5#, L-80 liner F/ 8895' - T/ 9285' MD. Started working down liner at 8065' with minimal effort. P/U and slack back off working thru set down points. Worked pipe clean 2x before making up SLZXP assy. 117k up, 51k dn (clean wts).;C/O handling equipment for 5" DP. M/U SLZXP assy as per BOT rep (Rick Babcock). M/U ball seat and burst disc sub. (8 screws pinned shear @ 2650 psi) (14 screws pinned neutralize @ 4200 psi). M/U 1 std 5" dp out of derrick. Break circulation - 1 bpm/125 psi, 2 bpm/235 psi, 3 bpm/415 psi.;Attempt to pump 4 bpm, saw psi climb 725 psi. New rate 2 bpm w/ 575 psi. B/D TDS and continue run liner on drill pipe.;Continue working 4.5" injection liner down while running in on 5" NC50 drill pipe out of derrick F/ 9324' - T/ 10,589' MD. Started rotating down @ 9975' MD w/ 12k max tq, 10-12 rpms. Multiple soft stall with clean break overs while working down. 20-30 fpm running speed when clean.;PJSM Cont wash/ ream down 4.5" Liner W/ 5" D.P. F/ 10,589' to 11,086' MD 10-12 RPM, Trq limit set at 12K. 2 bpm, Press limit set 800 PSI. Max Gas 442U. P/U 145K, SLK 55K. Working numerous tight spots, no issue breaking over on up stroke. pack off during reaming walked up Press F/ 400 to 800 PSI.;During working tight spot at 11,092' was slacking off and was unable to move string at 11,086' MD. Still had Circ W/ no Press spike. Work string multiple times F/ 205K (22'' Pipe Stretch) to 35K. Set TRQ in string F/ 13, 14 & 15K working string with no success.;Appears hung up at SLZXP at ~1,775' MD. Cont working string up to 350K (35K Block Wt) attempting to pull free. Contacted town and discussed fishing operations. Baker Fishing Rep and tools coming out. Cont. working string.;Daily fluid hauled to G&I 52 bbls total = 14,759 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 0 lbs, total =24 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,130 bbls Daily Fluid lost 40 bbls total production = 53 bbls Fluid lost surface hole 37 bbls. g pg RIH W/ 4.5" 13.5# L-80 W625 Liner to 1,506' MD. Install Centralizers and stop rings Run Liner Continue run 4.5" Hydril 625, 13.5#, L-80 liner F/ 6079' - T/ 8895' MD. )g 13, 14 & 15K working string with no success.;Appears hung up at SLZXP at ~1,775' MD. Cont working string up to 350K (35K Block Wt) attempting to pull free. gg pp gp ggp Contacted town and discussed fishing operations. Baker Fishing Rep and tools coming out. Cont. working string.;Daily f gg tight spot at 11,092' was slacking off and pgppggp gg was unable to move string at 11,086' MD. Still had Circ W/ no Press spike. Work string multiple times F/ 205K (22'' Pipe gpgp(p gqp r. POOH laying down 5" NC50 drill pipe F/ STUCK LINER !!!! 4/2/2020 Continue to work stuck 4.5" liner @ 11,086' MD. Attempt to work pipe up, Stage up F/ 300k to 400k in 50k increments slacking of to block wt with no trapped tq (no go). Worked pipe dn w/ 60k to 150k up, 18.2k right trapped tq. Moved pipe dn 10" with free rotation, 5 rpm, 13k tq, 150k rot wt.;Continue working pipe from block wt up to 200k varying parameters. Saw stalls when picking up above 160k and would stall on the down stroke @ block wt w/ 18.5k tq. M/U bumper jars w/ 1x jt 5" HWDP above table for bumping down operations. Discuss with drilling engineer (Joe Engel).;Proper build assembly of SLZXP was in question after discussion with Baker. Decision made to release from packer and move forward a path to retrieving liner and packer assy, ensuring positive slip and element engagement on depth.;Put 2 wraps left hand rotation w/ 7.5k tq while parked @ 80k. Work tq down hole and release from liner without issue. TOF @ 1775.10', Btm of liner @11068' MD. Monitor well (static). POOH on elevators F/ 1775' to surface. L/D LRT. LRT showed sheared hydraulic tool sleeve.;Liner running tool also showed positive indicators of mechanical left hand release. Believed that hydraulic setting tool shifted mechanically for working pipe. No indications of it shifting from hydraulic force. ball seat, circ sub and disc all uncompromised and intact. Send LRT to shop for insp;Clean and clear rig floor. Bring fishing tools to rig floor. Verify OD's, IDs and lengths. Perform thorough derrick inspection prior to picking up fishing BHA.;M/U Fishing assy - 6.22" ITCO grapple, grapple extension, 7-1/8" stop ring, XO, Bowen bumpers, Bowen Jars, 14x jts 5" NC50 HWDP, Bowen Intensifiers = 478.45' total length. RIH w/ 20 stds 5" dp out of derrick F/ 478' - T/ 1760' MD. 82k up, 78k dn.;Wash dn 3 bpm, 60 psi, 78k dn, 82k up, Landout on TOF @ 1,777' (spear nose @ 1798') w/ 5k dn. P/U to 101k (fish on). Jar @ 1 ea 150K, 160K, 170K, 180K, 190K. 20 X @ 200K, Work down 14X. Jar 31 X @ 225K, 35 X @ 250K, 5 X 270K. Straight pulled 300- 325K after each time.;Mob Milling tools F/ Baker in Deadhorse. Cont Jar 65 X @ 250-260K W/ straight pull 300-325K after each jar. Release F/ Fish W/O issue as per Baker Rep. Static loss rate ~3 bph.;PJSM Perform full Derrick inspection, drilling line, crown and Top drive. Rack back 1 stand 5" D.P. in Derrick and blow down,. P/U 81K, SLK 76K;PJSM Hang Blocks. Cut drilling line 80' (13 Wraps). Remove Deadman. 1,193' left on spool. Accum TM 30,098. Check Brakes, good. Unhang Blocks and calibrate Drawworks.;PJSM Grease Top Drive and Blocks.;PJSM POOH racking back 5" D.P. and 7 stands 5" HWDP F/ 1,751' MD. L/D Bowen Intensifier & Spear Assy. Grapple looked good. Lost 3.4 bbls for trip.;PJSM Clean and clear rig floor. P/U Baker milling assy components to rig floor.;PJSM P/U M/U 8.5" Packer Mill, 4 ea 7" Boot Baskets, 6 1/8" Bit Sub (No Float), 8 1/8" Xtreme XP Magnet, 6 1/4" Bowen Bumper Sub, 6 1/4" Bowen Oil Jar and 7 stands 5" HWDP and 16 jnts 5" HWDP off Skate (Drift 2.75") Total 982.37'.;Daily fluid hauled to G&I 114 bbls total = 14,873 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 2 lbs, total =26 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,130 bbls Daily Fluid lost 54 bbls total production = 107 bbls Fluid lost surface hole 37 bbls. 4/3/2020 RIh W/ 8.5" Mill Assy W/ 5" D.P. F/ 982' to 1,746'. Wash down at 8 bpm, 220 psi to 1,779' md. TOF 1,779'. Loss 1.1 bbls.;Start milling ops. F/ 1,779' to 1,799' md 8 bpm, 240 psi, 80-100 rpm, trq 5-8k, WOB 15-25K. P/U 90K, SLK 87K, rot 89K. At 1,795' md pack off, stop rpm & pumps. Pull 35k over to free. Work to neutral wt. establish parameters. Pump 20 bbl Hivis 50% inc metal. resume milling.;PJSM Cont milling operations F/ 1,799' to 1,800' MD. Milled total 21' of SLZXP. 8 BPM, 240 PSI, 100 RPM, TRQ 6-12K, WOB 17-30K, P/U 90K, SLK 87K, ROT 89K. Pump 25 bbl Hi Vis, 20% inc metal. Total metal captured at Shakers 450#.;PJSM Blow down Top Drive. Monitor well for 10 min, static. Pump down bleeder to flush flowline. POOH W/ 8.5" Mill Assy F / 1,800' to 57' MD. Pull 5 stands and monitor for swabbing, good. Rack back 13 stands 5" D.P. L/D 16 Jnts 5" HWDP. Rack back 7 stands 5" HWDP. No losses.;PJSM Trq lift sub. Service break milling Assy. L/D 8.5" Mill 1/16 under gauge, mill face worn but not worn out. Magnet was completely packed with metal. Boot baskets full of metal. Clean out Boot Baskets. Total Metal F/ Boot Baskets 105#.;PJSM Clean and clear rig floor of Milling Assy. Johnny Whack Stack. Blow thru Choke and Kill. Flush flow line W/ rig pumps.L/D Johnny Whacker and working single. Blow down all lines. Load floor W/ Spear Assy. Metal recovered F/ Magnets 50#. Total Metal recovered F/ milling 605#.;PJSM Grease Crown, Top Drive and Blocks. Pre jarring inspection.;P/U M/U Itco Spear W/ 3.885" Grapple, 4 3/4" Pup, X/O, 6 1/4" Bowen Bumper Sub, 6 1/4" Bowen Oil Jar, 14 stands 5" HWDP, 6 1/4" Bowen Intensifier total length 478.58' MD.;Daily fluid hauled to G&I 57 bbls total = 14,930 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 605 lbs, total =631 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,260 bbls Daily Fluid lost 35 bbls total production = 142 bbls Fluid lost surface hole 37 bbls. 4/4/2020 Trip in hole w/ BOT ITCO 3-1/8" spear assy dressed w/ 3.885" grapple. F/ 478' - T/ 1751' MD. Establish parameters - 3 bpm, 250 psi, 80k up, 80k dn. Wash down tagging TOF @ ~1799' MD.;S/O engaging fish w/ 5' swallow to 1805' MD. Set dn 7k, P/U w/ 20k overpull. Begin jarring operations - Stage up firing jars @ 150k up w/ 200 straight pull, 200k up w/ 250k straight pull, 250k up w/ 350k straight pull. Continue jarring w/ 250k up and 350k straight pull after firing jars each time.;No movement up. Attempt to work down F/ 150k - T/ blk wt (35k). No movement after 1 hr bumping down, continued jarring up @ 250k up w/ 350k straight pull. 56" stretch (200k up to 300k) indicating free @ packer and stuck point is in open hole.;Perform post jarring derrick inspection at crew change. Inspect drilling line, drawworks, traveling equipment along with TDS carriage (good).;Continue jarring 250k up w/ 350k straight pull (no movement). Attempt to release F/ fish with 1-1/4 right hand tq, work dn and up to release (no release). Rotate off fish w/ 10 rpm, 3-7k tq while slowly picking up. Released from fish without issue. L/D working single.;Monitor well (static). B/D TDS. POOH F/ 1800' to surface. B/O and redress spear assy w/ new grapple (3.885"). Old grapple had locked on to fish due to metal debris embedded in grapple, holding it engaged.;PJSM RIH W/ 7 stands 5" HWDP F/ Derrick and P/U M/U 6 1/4" Bowen Intensifier to 878' MD. Cont RIH singles off the Skate 5" HWDP F/ 479' to 1,710' MD (Drift OD 2.75") P/U 102K, SLK 102K.;PJSM Service Iron Roughneck, Grease Crown. Inspect Derrick and Top Drive. Checked gear oil. Perform drill line inspection. Static loss rate 1.2 bph.;PJSM Wash down F/ 1,710' to 1,799' MD 3 bpm, 330 PSI, P/U 104K, SLK 106K. Set down 15K, P/U 20K, set down 25K, P/U 45K. Set down string weight (65K) and mark pipe. Stage up W/ 175K to 200K and slack down to 35K working string down. Straight pulling up to 350K. No movement. Max Gas 272U.;PJSM Inspect drilling line, crown sheaves, Drawworks and welds on Top Drive carriage.;PJSM Cont attempting working string down W/ 200K up and down to 35K . Straight pulling up to 350K. No movement. Straight pull to 382K no movement. W 625 Jnt Yield 279K. Max Gas 182U.;PJSM Start jarring operations staging F/ 225K to 290K, while straight pulling to 375K, performed 126 X.. 3 bpm, 285 PSI, Max Gas 50U. No movement.;Daily fluid hauled to G&I 0 bbls total = 14,930 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 0 lbs, total =631 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,390 bbls Daily Fluid lost 45 bbls total production = 187 bbls Fluid lost surface hole 37 bbls. Continue to work stuck 4.5" liner @ 11,086' MD. 4/5/2020 Perform psot jarring derrick inspection (good). Inspect drilling line, drawworks and traveling equipment (good). Continue working to free 4.5" liner (TOF @ 1795', BOF @ 11,086' MD). Work F/ 225k to 290k. Straight pull to 382k max with no movement. 3 bpm, 285 psi. Decision made to release.;Attempt to conventional release grapple from fish (no go). Rotate off fish w/ 15 rpm, 3-7k tq while picking up slowly to release (success). 104k up clean wt.;Monitor well (static). POOH laying down F/ 1833' - T/ 478' MD. Continue trip out racking back to surface. B/O and L/D BOT fishing tools. 4.8 bbl loss for trip. Grapple assy looked good but did have debris packed in assy.;Svc rig. Grease traveling equipment, drawworks.;R/U Weatherford casing equipment to run 2-3/8" tapered string. Mob BOT 2-3/8" tools to floor. Obtain ID's, OD's and lengths. Load and process 308 jts 2-3/8" W 503 drill pipe in shed. M/U 5" safety joint and stage in shed.;PJSM P/U M/U 3.7" Junk Mill, 4.5" Scraper, Bit Sub, X/O's to W 503 Total 8.52'.;PJSM Single in hole Clean out BHA W/ 2.375" W 503 4.7# L-80 F/ 8.52' to 1,801' MD. P/U 41K SLK 43K. Weatherford TRQ 1,800 ft/lb. Fill at 1,000' MD. Drift OD 1.8". Lost 6 bbls.;Work string W/ Baker Rep. Set down 3K at 1,801.5' MD. ROT string in 1/4 and full turns W/ RLA without success. L/D Single and R/U X/O's & Head Pin 1502 W/ HP Hose. Fill DS and obtain parameters, .5 bpm 58 PSI, 1 bpm 80 psi, 1.5 bpm 130 PSI, 2 bpm 215 PSI. R/D Circ line. P/U single P/U 41K, SLK 44K.;Work string W/ RLA saw 3K bobble work down F/ 1801.5' to 1,803' MD appear to tag up on 4.5" Scraper. Cont working string W/ RLA 1/4 turns to full rotations and string weight 3K without success. M/U X/O's and Kelly Up. P/U to 1,797' obtain parameters 1.25 bpm 108 PSI, 2 bpm 210 PSI, 3 bpm 390 PSI;4 bpm 615 psi, 5 bpm 890 psi. Work string W/ 1-3 bpm, 3K still tagging scrapper at 1,801.5' W/ no change on pump Press. Tried to hydraulic off at 5 bpm 890 psi and cycle pumps on & off to try and slip by. Set TRQ limit 500 ft/lb. At 1 RPM 340 ft/lb TRQ working down to stall and tagging @ scraper.;Kelly down, L/D X/O's. Work down W/ full string weight in elevators W/ no success. P/U 41K, SLK 44K. Decision was made to POOH and try without scraper. Lost 18 bbls.;PSJM POOH L/D 2.327" to Pipe Shed F/ 1,801' to 8' MD. Lost 4.6 bbls.;PJSM L/D 4.5" Scraper new BHA 3.7" Junk Mill, Bit Sub and X/O total 5.27'. Junk Mill face looked good. 4.5" Scraper did not show exces sive wear or definitive signs. Clean and clear rig floor.;PJSM Single in BHA W/ 2.375" W 503 4.7# L-80 F/ 5.27' to 1,776' MD. P/U 41K SLK 43K. Weatherford TRQ 1,800 ft/lb. Lost 6 bbls.;Daily fluid hauled to G&I 57 bbls total = 14,987 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 8 lbs, total =639 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,390 bbls Daily Fluid lost 50 bbls total production = 237 bbls Fluid lost surface hole 37 bbls. 4/6/2020 Obtain parameters w/ 3.7" mill assy @ 1776' MD. 2 bpm, 204 psi, 42k up/dn/rot, 5 rpm, 680 ft/lbs tq. S/O and engage TOF @ ~1801' MD w/ 3.7 junk mill on 2- 3/8" TSH 503 work string. Saw 200-800 ft/lbs tq increase w/ 1-2k wob @ 5 rpm. Unable to make progress milling past obstruction (2 hrs).;P/.U and monitor well (static). POOH laying down 2-3/8" work string F/ 1801' to surface. 3.7" Junk mill showed no dull characteristics, stabilizer directly above mill showed very light scarring on blades w/ no other notable damage or markings to BHA. 2.7 loss for trip out.;Clean and clear rig floor. Mob BOT tools to rig floor for next run. Obtain ID's, OD's and lengths of tools. M/U 3.75" tapered mill w/ 3.8" string mill xo to 4-1/2 IF, 14x jts 5" NC50 HWDP (457.67' total length). RIH F/ 457.67' - T/ 1794' on 5" dp out of derrick.;Obtain parameters @ 1794' w/ 3.75" mill assy. 6 bpm, 600 psi, 78k up/rot/dn, 40 rpm, 2.1k tq. Slack off before taking wt @ 1803' MD. Dressed TOF F/ 1803' to 1805 then tq and wt cleaned up. Slacked off without rotation from 1807' to 1820.5' MD (upper 3.8" mill @ 1803'). Set dn 3k.;P/U and establish rotation @ 40 rpm w/ same parameters. Dress down F/ 1820' - T/ 1822' before wt and tq cleaned up. Slacked off with no rotary F/ 1822' - T/ 1825' MD clean. Reamed back up w/ minor tq spikes until clear of TOF. Attempt to slack off without rotary into TOF, Set dn 5k @ 1801' MD.;Pick up and slowly rotate down in TOF w/ 5 rpm. Engage TOF and attempted to trip thru. Took wt @ 1803' MD. P/U and continue to dress F/ 1803' down to 1,825' MD. Reamed back up W/ minor trq spikes to 1,799' MD. No pumps SLK set 3K at 1,801' MD. 2-3 rpm rolled in TOF. SLK to 1,825' clean.;Max Gas 31. Phase 1 @ 18:47. Notified AOGCC of upcoming BOP test via email @ 19:19 hrs.;At 1,825' MD Pump 25 bbl Hi Vis sweep 300 vis 9.5 bpm, 1,400 PSI, Max Gas 21U. No increase at Shakers. Monitor well for 10 min, static. Blow down Top Drive.;PJSM POOH racking back 5" D.P & 5" HWDP F/ 1,825' to BHA. L/D 3.8" String Mill, 3.75 Taper Mill BHA. 3.8" String Mill (3.75" OD) showed good sign of wear, 3.75" Taper Mill (3 11/16" OD) nose showed no sign of damage, taper had very minute wear high up, full gauge neck worn smooth. Lost 5.2 bbls.;PJSM P/U M/U as per Baker Rep 3.7" Junk Mill, 4.5" Scraper, 3 1/8" Bit Sub, X/O's total length 8.52', Single in hole W/ 2.375" W503 to 774' MD. Weatherford TRQ W503 to 1,800 ft/lb. Drift OD 1.8".;At 23:00 Phase 2 weather condition. Minimize operations around the rig, reduce running speed and no outside work due to weather conditions.;PJSM Cont single in hole W/ 2.375" W503 to 774' to 1,779' MD. R/U X/O and HP line. Pump at 1 bpm 88 PSI, 2 bpm 206 PSI, 3 bpm 280 PSI, 4 bpm 601 PSI, 5 bpm 870 PSI. Weatherford TRQ W503 to 1,800 ft/lb. Drift OD 1.8". Lost 4 bbls for trip.;PJSM P/U Jnt 59 RIH tag at 1,803' MD. P/U 41K, SLK 42 K. Work string W/ RLA ¼ to full turns setting down 3K. Work down W/ string weight numerous times. Kelly up Circ 2 bpm 195 PSI P/U 42K SLK 41K work down 5X. Set TRQ limit 500 ft/lb. ROT @ 1-2 RPM ROT 44K working string to 38K.;Stage up TRQ limit to 1,100 ft/lb with no success. Shut down pumps and ROT. Adjust Top Drive in bowl working F/ 1,802’ to 1,803’ MD saw 3K bobble 38K to 41K appears 3.7 Mill fell in TOF. R/D X/O’s blow down.;Cont single in hole 2.375" W503 F/ 1,805' to 2,071' MD P/U 41K SLK 38K Working each joint down, clean pick up wt slacking to string weight coming down. Possible debris in 4.5" Liner.. Weatherford TRQ W503 to 1,800 ft/lb. Drift OD 1.8".;Tagged up at 2,071' MD. Working string weight multiple times. R/U X/O and Kelly up. Parameters .5 bpm 130 PSI, 1 bpm 180 PSI, 2 bpm 230 PSI, 3 bpm 450 PSI. P/U 42 SLK 43K. Work down at 3 bpm tagged same 2,071' no press spike. Set TRQ limit 1,300 ft/lb. ROT at 3 RPM 876 ft/lb ROT 44K;work down to stall at 1,300 ft/lb. P/U set limit 1,500 ft/lb. 5 RPM 1,091 ft/lb 3 bpm 450 PSI SLK lightly mill at 2,071' TRQ 1,110 to 1,450 ft/lb for 10 min. P/U Stop rotary. SLK to tag 2,071' MD. Cont light milling to shift debris 5 RPM TRQ 1,100-1,450 ft/lb 3 bpm 450 PSI.;Daily fluid hauled to G&I 57 bbls total = 15,044 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 10 lbs, total =649 lbs Daily water hauled from L Pad Lake 0 bbls total = 13,520 bbls Daily Fluid lost 35 bbls total production = 272 bbls Fluid lost surface hole 37 bbls. 4/7/2020 Continue work 3.7" mill assy F/ 2075' - T/ 2085' MD w/ 3 bpm, 450 psi, 42k up/dn/rot, 5-20 rpm, 1.2k free tq w/ stalls up to 1.8k.;Continue to RIH w/ 2-3/8" TSH 503 workstring F/ 2085' - T/ set down depth of 2328' MD (#9 ICD on tally). Pushing junk downhole to set down depth.;P/U and establish milling parameters @ 2320' MD. 20 rpm, 1.4k tq, 3 bpm, 500 psi. 43k up/dn/rot. Mill F/ 2328' - T/ 2361' MD. Saw tq w/ stalls @ 1.8k tq. Overpulled 2x w/ 15k over before breaking over. 1-3k wob. Very ratty. Appears to have junk in profile of ICD.;Continue to RIH w/ 2-3/8" TSH 503 workstring F/ 2361' - T/ 3367' MD. Set down @ 3367' MD (#8 ICD on tally). 45k up/dn.;Mill thru 2nd ICD (Flo-Fuse) w/ 3.7" junk mill / scraper assy F/ 3367' - T/ 3371' MD. 3 bpm, 600 psi, 30 rpm, 1.7k tq, 1-2k wob. B/D TDS.;Continue to RIH w/ 2-3/8" TSH 503 workstring F/ 3371' - T/ 4810' MD. Tripped thru ICD #7 (Flo-Ultra) clean without issue. Tripped thru all Swell Packers clean thus far. M/U XO for 2-3/8 503 X 5" NC50.;Continue RIH w/ 3.7" junk mill / scraper assy F/ 4810' to 5,636' MD. P/U 75K, SLK 68K W/ 5" HWDP & 5" D.P. Worked spots at 5,350', 5,390', 5,431', 5,473', ICD 5,513', 5,534' At 5,580' MD Broke Circ. at .75 BPM and string Press up to 1,500 PSI Junk Mill appears to be plugged. Lost 3.6 bbls.;PJSM Monitor well for 10 min, static. Blow down Top Drive. POOH racking back 5" D.P. & 5" HWDP F/ 5,636' to 4,810' MD P/U 56K, SLK 49K. Clean trip out. Lost 1.9 bbls.;PJSM Drain Stack. M/U X/O's and Wear Ring Pulled to workstring. Pull Wear Ring. P/U 56K, SLK 49K. P/U Test Plug and hang 2.375" work string.;PJSM Test PVT's, High Low level alarms, Test Choke Manifold valves 7-14 off line to 250 PSI low & 3,000 PSI high 5 min. SIMOPS R/U Test Equip & flood Stack. Shell test Stack 250 PSI/ 3,000 PSI, good. Lined up to start BOPE test and would not hole Press. Trouble shoot all surface Equip.;NOS re tighten LDS for test plug. Shell test Stack, good. Test W/ 3.5" test Jnt Annular, Upper & Lower Rams (2.875"X 5.5"), Choke valves 1-6 & 15, HCR Choke & Kill, Mezz Kill to 250 Psi low & 3,000 PSI high 5 min on chart. Witnessed waived by AOGCC Rep Adam Earl.;Daily fluid hauled to G&I 0 bbls total = 15,044 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 5 lbs, total =654 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,650 bbls Daily Fluid lost 40 bbls total production = 312 bbls Fluid lost surface hole 37 bbls. 4/8/2020 C/O upper pipe rams (VBR's 2-7/8" x 5.5"). Inspect door seals (good), m/u doors. Cycle 5x new elements and re-test upper rams w/ 3.5" test jt (test good). Continue testing 13-5/8" stack 250/3000 w/ 5 min hold on each. Chart and record same. AOGCC rep Adam Earl waived witness via email.;F/P on upper pipe VBR's (replaced and retested good), F/P on blind rams (cycled and retested good). Drawdown - Start 3000 psi, Drawdown 1500 psi, 200 psi inc 26 secs, Full recovery 97 secs, 6 bottle avg NO2 2316 psi.;B/D TDS. R/D test equipment. B/D manifold and stack. Svc manifold and BOP equipment. Pull and L/D test plug (54k up to w/ string hung off btm of test plug).;M/U head pin w/ HP hose. Circulate string volume to clear debris from junk mill assy @ 4810' MD. Circulated string without issue @ 3 bpm, 920 psi. R/D and B/D circulating equipment.;PJSM Break down magnet and X/O's. R/D 5" Handling Equip. R/U 2 3/8" Handling Equip and Weatherford tongs.;PJSM POOH 2 3/8" WS on elevators F/ 4,801' to Surface. Observed 5K bobble at 3,358' ICD, 4K @ ICD 2,319' MD, pulled thru TOF 1,803' clean. 3.7" Junk MIll face had minimal wear, Scraper had slight wear on pads. Lost 18 bbls for trip.;PJSM Clean and clear rig floor 2 3/8" handling Equip. Stage Cutter BHA on rig floor.;P/U working jnt and install Wear Ring (10" ID, 10.5" OD, 12.25" Lngt).;PJSM P/U M/U Cutter BHA as per Baker Rep. 3.125" Multi String Cutter, 3.125" Spear Extension, 3.125" Pup Jnt, 4.75" OD X/O, 3.5" Pup Jnt, X/O Sub & 5" HWDP total length 453'. Cutter knives to 4.75" No/Go 12.59'.;Cont RIH W/ 5" D.P. F 453' to 1790' MD. P/U 73K SLK 73K;Slack off to 1,817' to no/go. P/U 3.5" putting cutter blades at 1,813' MD. Obtain parameters TRQ limit set 4,000 ft/lb, 60 RPM 1,800-2,000 ft/lb. ROT 70K, Stop rotation, Pumps on 1.5 bpm 184 PSI, 2 bpm 626 PSI, 3 bpm 1,320 PSI, 4 bpm 2,565 PSI. Pumps down.;Start cutting operations. Start rotation 60 RPM TRQ 2,000 2,500 ft/lb 3 bpm 1,450 PSI, pump Press falling to 1,139 PSI TRQ erratic F/ 2,000 to 2,700 ft/lb cut for 24 min. Set down 1K ensure blades fully open 4 bpm 900 PSI TRQ smoothed out to 1,927 ft/lb. P/U to 1,790' MD P/U 78K SLK 77K.;PJSM Monitor well 10 min, static. Blow down Top Drive. POOH W/ 5" D.P & 5" HWDP F/ 1,790' to surface. L/D Cutter BHA as per Baker Rep onsite.;Daily fluid hauled to G&I 57 bbls total = 15,101 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 5 lbs, total =659 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,780 bbls Daily Fluid lost 18 bbls total production = 330 bbls Fluid lost surface hole 37 bbls. 4/9/2020 Grease traveling equipment. Svc iron roughneck and inspect TDS carriage.;M/U spear fishing assy dressed w/ 3.885" NOM catch grapple, CO, Bumpers, Oil Jars, 14x jts 5" HWDP - 460.40' total length. RIH F/ 460' - T/ 1733' MD. engage TOF @ 1803' and continue slack off to NoGo @ 1809' MD. 78k up, dn. P/U w/ no overpull.;Monitor well (static). POOH F/ 1809' to surface. B/O and L/D 12.11' fish (remaining xo, 4.5" pipe). B/O and L/D fishing assy. 7.5 bbls loss for total round trip. New TOF @ 1813' after cut.;M/U Overshot assy dressed w/ 4.5" basket grapple and plain control (no packoff) = 3.92' total length. RIH on 5" 19.5#, S-135 NC50 drill pipe F/ 4' - T/ 1786' MD.;Obtain parameters - 3 bpm, 65 psi, 10 rpm, 1.6k tq, 70k up/dn. RIH F/ 1786' - T/ 1815' MD engaging TOF. No Go @ 1815k w/ 20k dn 2x. P/U to 120k and set slips (dog collar and tie slip handles). B/D TDS.;MOB Ak E-line equipment to floor. PJSM, R/U sheaves and secure same. Perform pre-run checks as per Well Tech prior to running explosives (test good). M/U Tractors, 2-1/8" CCL, knuckle, wt bar, knuckle, adj cent to 4", 2500-200 RCT, 2.5" psi balance anchor and btm cent.;Zero at floor and RIH to 1800' WLM. Verify communication between WellTech and tractors (test good). Cont RIH E Line to 5,021' WLM, lost WT. P/U saw 1,200# line jump at 4,690' WLM. Correlated at ICD 4,516' WLM (16' adjust) RIH to 4,984' WLM Lost WT. RIH W/ tractor at 36 ft/min 350# to 5,202' WLM.;Correlate up at 50 ft/min 225# to 4,990' WLM CCL log very ratty showing 1' discrepancy. Cont P/U to 4,366' WLM logs looking clear. Decision was made to cut at 4,513' 1' below tool jnt on top ICD Pup. Correlated 2X W/ 6" adjustment. Pulled to CCL at 4495.2' CRT (17.8') 4,513' WLM.;tied into 4.5" Liner tally. Perform cut at 4,513' WLM line jump F/ 200# to 150#. No surface indication. POOH W/ ELine to Surface. Found 2 pieces of metal on ELine bow spring centralizers. 1/16"thick 2 3/8" X 2" and 1/8" thick 3/4" X 4 1/2". Static loss rate 1.8 bph.;PJSM P/U on Fish W/ Baker Rep onsite. Stage up F/ 175K to 235K (165K Over) string jumped, appears cut broke loss. Inspect Derrick, Top Drive and Drawworks, good. P/U wt 100K 30K over original string weight. Fish on. Lost 20 bbls for tour.;PJSM POOH W/ 5" D.P and 4.5" Liner F/ 4,513' to 2,698' MD. P/U 67K SLK 67K. Lost 1.1 bbls.;PJSM Release Overshot As per Baker Rep and L/D 4.5" cut Jnt 35.44'.;PJSM C/O Elevators and 5" handling Equip. R/U 4.5" Handling Equip and Weatherford Tongs. POOH L/D 4.5" Liner to Pipe Shed F/ 2,698' to 410' MD, Lost 5.4 bbls.;Daily fluid hauled to G&I 57 bbls total = 15,101 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 5 lbs, total =659 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,780 bbls Daily Fluid lost 18 bbls total production = 330 bbls Fluid lost surface hole 37 bbls. 4/10/2020 Cont POOH L/D 4.5" Liner F/ 410' to cut jnt 1.42' length. L/D 63 jnts 4.5" Liner, 3 ea SP OD's 8.25", 8.28" & 8.26" & 2 ea ICD's. Lost 7 bbls for trip.;Clean and clear rig floor. R/D 4.5" handling Equip R/U 5" handling Equip. P/U Baker fishing tools.;PJSM P/U M/U as per Baker rep onsite 8 1/8" S150 Overshot 3.92' W/ 4.5" Grapple, 6.25" Bumper Sub, 6.25 Oil Jars, 7 stands 5" HWDP & 6.25" Intensifier total length 468.9'. P/U 56K SLK 57K.;RIH Jarring Assy W/ 5" D.P. F/ 469' to 4,475' MD. Obtain parameters 10 RPM, TRQ 6.7K, 1 bom 100 PSI. P/U 132K SLK 109K ROT 121K. Lost 0.8 bbls.;TOF at 4,517' MD. Engage grapple at 4,520' MD P/U 132K SLK 109K.. 1 bpm 140 PSI, set down 20K, P/U 50K 3X, engaged. Start firing jars at 170K (300K wt indicator) stage up to 220K (350K wt indicator) straight pull to 350K. no movement. Pump at 0.5 bpm 80 PSI increase to 3 bpm 200 PSI.;With out any benefit Disconnect F/ TOF. Rack back stand and blow down Top Drive. P/U 132K SLK 109K ROT 116K.;PJSM Perform Jarring Derrick inspection. Grease Crown, Blocks, Iron Roughneck and Spinners.;PJSM POOH rcking back 5" D.P. F/ 4,472' to Surface. L/D Jarring BHA as per Baker rep onsite. Lost 5 bbls.;PJSM M/U new 8 1/8" S150 Overshot 3.92' W/ 4.5" Grapple W/ Pack off total length 3.92'. RIH W/ 5" D.P. to 4,456' MD. Lost 3 bbls. Fill drill string 1 bpm 90 PSI wash down and engage TOF at 4,517' Set 20K engage fish to 4,520' MD. Pull 50K over 3X. Set slips W/ 156K (22K over pull) Blow down.;PJSM M/U side entry Sub. R/U AK Eline Sheaves and tools. M/U Tractors, 4" Cent, ,2-1/8" CCL, 2500-200 RCT, 2.5" psi balance anchor and bottom Cent. Cut length CCl to RCT 12.9'.;RIH W/ ELine 100 ft/min Lost line weight at 4,520' WLM. Correlation correction 20' down. Tractor down at 30 ft/min to 5,707' WLM. P/U line work tight spot at 5,563' WT 3,200#. Pull to 5,373' WLM correlate 15' down. Tractor down to 5,707' WLM. P/U to CCL 5,583.1' RCT 5,596' WLM.;Line tension 1,500# after 1,460#. No indication on rig floor. Perform cut mid joint on Jnt 129.;Daily fluid hauled to G&I 0 bbls total = 15,258 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 0 lbs, total =659 lbs Daily water hauled from L Pad Lake 130 bbls total = 13,910 bbls Daily Fluid lost 36 bbls total production = 406 bbls Fluid lost surface hole 37 bbls. Tractor down to 5,707' WLM. P/U to CCL 5,583.1' RCT 5,596' WLM.;L Perform cut mid joint on Jnt 129. CUT liner at 5596' 4/11/2020 PJSM POOH W/ ELine F/ 5,596' WLM. L/D Tractor Asst and RCT Assy. R/D Eline sheave, pack off, X/O and pump in sub.;PJSM P/U on fish and attempt to work 4.5" liner free. String weight 132K stage up F/ 200K to 400K (268K over) without movement. Prep RCT and tractors for fourth run. Static loss 1.5 bph.;PJSM Set 40K over in slips. R/U ELine Sheave. Last P/U 120K, SLK 105K. Welltec setting up tractor for another run.;PJSM P/U M/U Tractors, 4" Cent, ,2- 1/8" CCL, 4000-200 extension RCT, 2.5" psi balance anchor and bottom Cent. Cut length CCl to RCT 13.9'. RIH and perform cut at 5,552' MD mid jnt on jnt 129. CCL at 5,538' cut at 5,552' WLM. Line jump 200# but no indication at rig floor. POOH L/D Tools.;PJSM Kelly up. Stage up in 15K increments up and slacking to 15K down F/ 150K to 400K (268K over) without movement. Disconnect off fish.;PJSM POOH F/ 4,517' L/D Overshot and grapple. lost 4 bbls for trip.;PJSM P/U M/U BHA as per Baker. 8 1/8" S150 Overshot 3.92' W/ 4.5" Grapple, 6.25" Bumper Sub, 6.25 Oil Jars, 2 stands 5" HWDP & 6.25" Intensifier total length 468.9'. P/U 56K SLK 57K.;PJSM RIH Jarring BHA W/ 5" D.P. F/ 469' to 4,478' MD. P/U 127K, SLK 107K Lost 2 bbls.;PJSM Inspect drill line spooler. Hang Blocks. Cut 100' wraps, (16). 1,093' left on spool. Accum TM 31329. Check Brakes, good. Unhang Blocks and calibrate Drawworks.;PJSM Service rig. Grease Crown, Top Drive and Blocks.;PJSM Start Jarring operations. Engage TOF @ 4,517', swallow to 4,520' MD. P/U 128K SLK 108K. 1 bpm 84 PSI, 2 bpm 97. Stage up 170K to 330K (200K over) for 39X. Cont firing at 330K (200K over) straight pulling to 350K 8X. Circ 2 bpm 221 PSI to cool Jars down.;Cont Jarring W/ 2 bpm 221 PSI firing at 330K W/ straight pull to 400K (270K over) 30X.;Daily fluid hauled to G&I 0 bbls total = 15,258 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 0 lbs, total =659 lbs Daily water hauled from L Pad Lake 0 bbls total = 13,910 bbls Daily Fluid lost 31 bbls total production = 437 bbls Fluid lost surface hole 37 bbls. 4/12/2020 PJSM Cont Jarring W/ 0.5 bpm 80 PSI firing at 330K W/ straight pull to 400K (270K over) No movement. Max Gas 170U.;PJSM Disconnect F/ TOF @ 4,517' MD as per Baker rep. Blow down Top Drive and POOH F/ 4,513' to BHA. P/U 131K SLK 107K.;PJSM L/D Intensifier, rack back 7 stands 5" HWDP, L/D Jars and Bumper Sub. Remove guide on Overshot. Check grapple and install pack off on 1 stand 5" D.P. Lost 3 bbls for trip.;PJSM RIH W/ 8 1/8" S150 Overshot pack off 3.92' W/ 4.5" Grapple on 5" D.P. to 4,517' MD. Engage TOF at 4,517' MD Set down 20K pull over 50K 3X. Lost 3 bbls for trip.;PJSM Stage Eline tools on rig floor. Hang sheave on tugger to M/U RIH Weltec Tractor, 1 3/8" CCL knuckle, 1 3/8" Slack Jaw, 1 3/8" Friction Centralizer, 1 3/8" Free Point & 1 3/8" Friction Centralizer. Run into 5" D.P. 100' WLM. Hang sheave on pad eye in Derrick. RIH ELine to 4,478' WLM.;Attempt to calibrate Free Point tool F/ 21:00 to 23:00. POOH to trouble shot tools.;PJSM Hang Sheave F/ Tugger and pull tools to surface. Service Tractors, oil, grease and C/O Orings. CCl flooded top spring on free point. Fixed CCL, Slack Jaw & Free Point top spring. RIH W/ ELine BHA Weltec Tractor, 1 3/8" CCL 1 3/8" Slack Jaw, 1 3/8" Friction Centralizer, 1 3/8" Free Point.;& 1 3/8" Friction Centralizer. Hang Sheave in Derrick and cont RIH. Calibrate Free Point and free at 4,542', 4,634’, 4,800’, 5,015’ & 5,450’ WLM. POOH.;Daily fluid hauled to G&I 62 bbls total = 15,320 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 0 lbs, total =659 lbs Daily water hauled from L Pad Lake 0 bbls total = 13,910 bbls Daily Fluid lost 30 bbls total production = 498 bbls Fluid lost surface hole 37 bbls. 4/13/2020 Cont POOH W/ ELine. L/D Tractor, CCL & Freepoint. Set string in tension 45K over (String WT 120K) Hang ELine sheave in elevators. C/U tools to RCT BHA.;Cleaning around rig and work on EAMS. Welltec setting up Tractor for cut run.;PJSM RIH W/ Eline Tractor, CCL, Anchor and RCT. CCL to RCT 20'. RIH and correlate. Cut 4.5" Liner at CCL 5,380' WLM RCT at 5,400' MD. Mid joint on Jnt 133. Good surface indication RCT fired. POOH. Static loss rate 1.5 bbls.;PJSM Out of hole at 12:10. L/D Tractor and cutting Assy. R/D Eline Sheave. Pull 126K 6K over string weight. 4.5" Liner free. POOH F/ 5,400' to 5,326' MD. P/U 126K, SLK 106K.;Kelly up and CBU at 5,326' MD. 600 GPM, 600 PSI. Reduced flow at surface to 420 GPM, 360 PSI due cold mud at surface running over Shakers. No debris seen at Shakers.;PJSM POOH racking back 5" D.P. and 5" HWDP F/ 5,326' to Overshot P/U 126K, SLK 106K.;PJSM . L/D Overshot as per Baker rep. C/O Equip F/ 5" to 4.5' and R/U Weatherford tongs. POOH 4.5" 13.5# Liner 892' to cut jnt. L/D 20 jnts 4.5", cut Jnt 9.20'. 1 ea Swell packer. Swell Packer showed wear from movement. 20 Centralizers, 21 Stop Rings. Cut Jnt had stop ring but no Centralizer.;PJSM L/D Baker and Weatherford tools and Equip.;PJSM RIH 7 stands 5" HWDP and POOH L/D 5" HWDP to Pipe Shed.;PJSM Stage Halliburton 9 5/8" EZ Drill SVB 7,500 PSI. M/U running Assy on 1st stand 5" D.P. as per Halliburton rep. Dummy run into 9 5/8" Csg. P/U and install packer. RIH W/ 5" D.P. at 90 ft/min as per Halliburton to 5,300' MD.;PJSM Break Circ. 210 GPM, 250 PSI. Move string F/ 5,300' to 5,280' MD ensure setting area clear of debris.;PJSM Set Halliburton CIBP at 5,300' MD. Rotate string 35X right, P/U 10K wait 1 min, P/U another 10K wait 1 min. P/U to shear off at 184K (64K over). Re nter CIBP and set down 5K. Attempt to test CIBP to 2,500 PSI, failed. Checked all surface Equip. Set down another 10K, 15K total and tried again,;failed. P/U out of CIBP to 5,282' MD. Closed in Annular and pump down string to test, still would not hold. Set down 26K and tested, failed. P/U 5" Pup and set down 50K and test. And attempt to test. failed. Set down 20K Closed Annular and started injection rates W. 9.3 ppg MW;at 0.5 bpm 5 bbls away 225 PSI, 1 bpm 10 bbls away 395 PSI, 1.5 bpm 15 bbls away 575 PSI, 2 bpm started injecting at 42.2 bbls away 890 PSI settling at 860 PSI injecting at 2 bpm total injected 50 bbls. Initial shut in Press 860 PSI after 10 min 613 PSI slowing to 10 PSI a min. Bleed down.;Flow back 36 bbls back to pits.;PJSM R/U for Cement Job. M/U 5' Pup, Head Pin, LoTRQ and HP hoses. Pump 5 bbls H2O at 0.25 bpm 220 PSI. PT Halliburton line to 1,380 PSI low kick out, 3,230 PSI high.;Daily fluid hauled to G&I 57 bbls total = 15,377 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 0 lbs, total =659 lbs Daily water hauled from L Pad Lake 360 bbls total = 14,270 bbls Daily Fluid lost 30 bbls total production = 428 bbls Fluid lost surface hole 37 bbls. Pull 126K 6K over string weight. 4.5" Liner free. POOH ;Attempt to calibrate Free Point tool gg M/U RIH Weltec Tractor, 1 3/8" CCL knuc PJSM POOH W/ ELine F/ 5,596' WLM. L/D Tractor Asst and RCT Assy. gg gp Cut 4.5" Liner at CCL 5,380' WLM RCT at 5,400' MD. liner free RCT cut at 5400 ft p Set Halliburton CIBP at 5,300' MD. 4/14/2020 Cont cement job. Line up Halliburton to drill string. Pump 10 bbls H2O 2 bpm, 631 PSI. Mix and pump (PlugChem) 50 bbls (246sx) 15.8 ppg cement 2 bpm ICP 742 PSI FCP 147 PSI. Pump 5 bbls H2O 2 bpm, 68 PSI. Come on W/ rig pumps at 4 bpm ICP 217 PSI, caught cement about 15 bbls;away stage down to 1.5 bpm FCP 700 PSI W/ 70.8 bbls 9.30 ppg Quickdril CIP at 07:09. 35 bbls below CIPB and 15 bbls on top. R/D Halliburton cement lines.;PJSM POOH F/ 5,300' to 4,897' MD. P/U 127K, SLK 106K. POOH at 25 ft/min to let cement fall out string.;PJSM Kelly up and drop 6" Wiper Ball in string. F/ 4,897' Circ surf to surf at 294 GPM, 230 PSI. Trace cement seen at BU. C/O to Hydraulic elevators. Blow down Choke and Kill lines. P/U 122K SLK 103K.;PJSM Monitor well 10 min, static. Pump Dry Job. Blow down Top Drive and install striping rubber. POOH L/D 5" D.P. to Pipe Shed F/ 4,897' to RTTS running tool.;PJSM Break down cement head pin and equip F/ Pipe Shed.;PJSM Service rig. Grease Crown, Blocks, Top Drive, Spinners and C/O HPU high Press filters.;PJSM P/U M/U 9 5/8" RetrivoMatic as per Baker Rep. Test slip function W/ tugger.;PJSM RIH W/ test packer to 1,030' test to 330 PSI, good, 1,917 1,500 PSI good, Failed testing W/ 1,000 PSI at 4,800', 4,586', 4,484', 4,391', 4,200' & 3,818' MD. Passed at 3,310' 1,000 PSI. RIH to 3,564' & test failed 3,564', 3,500', 3,437' & 3,373' M. Test to 1,000 PSI at 3,342' Pass.;Hole between 3,342' & 3,373' MD. 9 5/8" collars at 3,346' & 3,386' MD.;PJSM POOH racking back 5" D.P. F/ 3,342' to RTTS running tool. L/D as per Baker.;PJSM P/U M/U Baker K1 9 5/8" CIBP as per Baker Rep. RIH W/ 5" D.P. to 3,320' MD. P/U 101K SLK 86K.;PJSM Set CIBP as per Baker Rep. 11 turns to right, pull 40K over and set down 30K 2X. PT to 2,500 PSI, good. P/U 103k string weight & rotate 5 turns to right freeing running Assy.;PJSM Flood lines. Test 9 5/8" Csg to 2,500 PSI for 30 min. Pumped 2.1 bbls, bled back 2.1 bbls. Bleed off R/D and blow down.;Pump Dry job and blow down. POOH L/D 5" D.P. to Pipe Shed F/ 3,318' to 3,262' MD. P/U 99K SLK 83K.;Daily fluid hauled to G&I 57 bbls total = 15,434 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 2 lbs, total =661 lbs Daily water hauled from L Pad Lake 50 bbls total = 14,320 bbls Daily Fluid lost 115 bbls total production = 643 bbls Fluid lost surface hole 37 bbls. 4/15/2020 PJSM POOH L/D all 5" D.P. to Pipe Shed. L/D Baker CIBP running Assy.;PJSM M/U Wear Ring puller, BOLDS pull Wear Ring.;PJSM Service rig. Grease Crown, Top Drive, Blocks and Spinners.;PJSM Clear and clean rig floor. C/O Elevators to 3.5", R/U Weatherford tongs and handling Equip.;PJSM RIH 3.5" 9.3# 8rd EUE Kill String W/ 5.74' Mule Shoe to 2,392' MD TRQ to 3.2K (drift 2.867" OD).;PJSM Lower coffin door and replace leaking ORing on bull plug on Hydraulic manifold on Top Drive.;Cont RIH 3.5" 9.3# 8rd EUE Kill String F/ 2,392' to 2,748 MD TRQ to 3.2K (drift 2.867" OD).;PJSM C/O elevators to 5". P/U 5" D.P. Jnt M/U Hanger as per NOS and land Kill String at 2,783' MD. 18K on Hanger. P/U 56K, SLK 53K. RILDS. L/D Landing jnt. P/U Tee Bar and install BPV.;PJSM Flush all surface Equip W/ fresh water. Top Drive, Choke and Kill lines, Choke Manifold and blow down.;PJSM Pull riser, remove Choke and Kill lines, rack back BOPE on pedestal and secure. Remove 11" X 13 5/8" DSA F/ Well Head.;PJSM INstall CTS on BPV. Prep Well Head and set down Dry Hole Tree. Test Tubing Hanger void to 500 PSi low and 5,000 PSI high. R/U and test Tree to 500 PSI 5 min 5,000 PSI Min. Prep for Freeze Protect. SIMOPS C/O Saver Sub on Top Drive to HT38.;Prep Pipe Shed. Bridle up. Cont clean Pits. Inspect MP #1.;PJSM Pull CTS and R/U HP lines. Freeze Protect well W/ 196 bbls Diesel pumping W/ MP #2 at 2 bpM, ICP 204 PSI FCP 450 PSI taking returns down drag chain to cutting box. Blow down and flush all lines W/ H2O. Install Otis flange on Tree and test to 500 PSI 5 min 5,000 PSI 10 Min.;PJSM Scope down Derrick. Cont cleaning Pits. Inspect MP #2.;Daily fluid hauled to G&I 409 bbls total = 15,843 bbls Daily fluid hauled to Kup 1B total = 228 bbls Daily metal recovered 0 lbs, total =661 lbs Daily water hauled from L Pad Lake 125 bbls total = 14,445 bbls Daily Fluid lost 0 bbls total production = 643 bbls Fluid lost surface hole 37 bbls. pump cement through EZSV (CIBP?) Line up Halliburton to drill string. Pump 10 bbls H2O 2 bpm, 631 PSI. Mix and pump (PlugChem) 50 bbls (246sx)15.8 ppg cement 2 bpm ICP jp gp p pp(g)()ppg p 742 PSI FCP 147 PSI. Pump 5 bbls H2O 2 bpm, 68 PSI. Come on W / rig pumps at 4 bpm ICP 217 PSI, caught cement about 15 bbls;away stage down to 1.5yppgp p p bpm FCP 700 PSI W / 70.8 bbls 9.30 ppg Quickdril CIP at 07:09. 35 bbls below CIPB and 15 bbls on top. Test 9 5/8" Csg to 2,500 PSI for 30 min. g g RIH W/ 5" D.P. to 3,320' MD. P/U 101K SLK 86K.;PJSM Set CIBP as per Baker ppp Rep. 11 turns to right, pull 40K over and set down 30K 2X. PT to 2,500 PSI, good. gp g land Kill String at 2,783' MD. 18K test casing hole at 3400 ft approx . CIBP at 3320 ft Test Tubingp Hanger void to 500 PSi low and 5,000 PSI high 13 April, 2020 Milne Point M Pt S Pad MPU S-56PB1 500292366970 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-56i MPU S-56PB1 Survey Calculation Method:Minimum Curvature MPU S-56i Actual RKB @ 63.51usft Design:MPU S-56PB1 Database:NORTH US + CANADA MD Reference:MPU S-56i Actual RKB @ 63.51usft North Reference: Well MPU S-56i True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Milne Point, ACT, MILNE POINT Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: MPU S-56i usft usft 0.00 0.00 5,999,884.82 565,478.70 36.90Wellhead Elevation:usft0.50 70° 24' 36.487 N 149° 28' 0.588 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) MPU S-56PB1 Model NameMagnetics BGGM2019 3/15/2020 16.01 80.83 57,368.08354248 Phase:Version: Audit Notes: Design MPU S-56PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:26.61 349.060.000.0026.61 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 4/13/2020 Survey Date 3_Gyro-GC_Csg H049Gb: North seeking on wireline in casing55.00 1,621.00 MPU S-56PB1 E-Line Gyro (MPU S-56P 03/02/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa1,717.59 5,308.30 MPU S-56PB1 MWD+IFR2+MS+Sag (1) 03/17/2020 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa5,384.94 14,430.60 MPU S-56PB1 MWD+IFR2+MS+Sag (2) 03/26/2020 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26.61 0.00 0.00 26.61 0.00 0.00-36.90 5,999,884.82 565,478.70 0.00 0.00 UNDEFINED 55.00 0.27 51.13 55.00 0.04 0.05-8.51 5,999,884.86 565,478.75 0.95 0.03 3_Gyro-GC_Csg (1) 115.00 0.30 49.75 115.00 0.23 0.2851.49 5,999,885.05 565,478.98 0.05 0.17 3_Gyro-GC_Csg (1) 175.00 0.37 46.10 175.00 0.47 0.54111.49 5,999,885.29 565,479.24 0.12 0.36 3_Gyro-GC_Csg (1) 235.00 0.42 28.71 235.00 0.80 0.79171.49 5,999,885.62 565,479.48 0.22 0.63 3_Gyro-GC_Csg (1) 295.00 0.44 43.43 295.00 1.16 1.05231.49 5,999,885.98 565,479.74 0.19 0.93 3_Gyro-GC_Csg (1) 355.00 0.78 40.40 354.99 1.63 1.47291.48 5,999,886.47 565,480.16 0.57 1.32 3_Gyro-GC_Csg (1) 416.00 1.02 37.26 415.98 2.38 2.07352.47 5,999,887.22 565,480.75 0.40 1.95 3_Gyro-GC_Csg (1) 478.00 1.30 51.11 477.97 3.26 2.95414.46 5,999,888.11 565,481.62 0.64 2.64 3_Gyro-GC_Csg (1) 541.00 2.21 70.31 540.94 4.12 4.65477.43 5,999,888.98 565,483.32 1.70 3.16 3_Gyro-GC_Csg (1) 604.00 3.65 84.17 603.86 4.73 7.79540.35 5,999,889.62 565,486.45 2.53 3.17 3_Gyro-GC_Csg (1) 635.00 4.89 83.41 634.77 4.99 10.09571.26 5,999,889.89 565,488.74 4.00 2.98 3_Gyro-GC_Csg (1) 4/13/2020 12:47:00PM COMPASS 5000.15 Build 91E Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-56i MPU S-56PB1 Survey Calculation Method:Minimum Curvature MPU S-56i Actual RKB @ 63.51usft Design:MPU S-56PB1 Database:NORTH US + CANADA MD Reference:MPU S-56i Actual RKB @ 63.51usft North Reference: Well MPU S-56i True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 667.00 5.35 88.25 666.64 5.19 12.93603.13 5,999,890.12 565,491.59 1.97 2.64 3_Gyro-GC_Csg (1) 731.00 5.31 102.54 730.37 4.64 18.81666.86 5,999,889.62 565,497.46 2.07 0.98 3_Gyro-GC_Csg (1) 794.00 5.11 120.38 793.11 2.58 24.07729.60 5,999,887.61 565,502.75 2.58 -2.03 3_Gyro-GC_Csg (1) 858.00 5.38 143.29 856.85 -1.26 28.32793.34 5,999,883.81 565,507.03 3.28 -6.62 3_Gyro-GC_Csg (1) 922.00 6.75 172.61 920.51 -7.40 30.60857.00 5,999,877.69 565,509.36 5.22 -13.07 3_Gyro-GC_Csg (1) 985.00 7.68 183.86 983.01 -15.27 30.80919.50 5,999,869.82 565,509.63 2.68 -20.84 3_Gyro-GC_Csg (1) 1,049.00 8.93 172.97 1,046.34 -24.47 31.12982.83 5,999,860.63 565,510.03 3.13 -29.93 3_Gyro-GC_Csg (1) 1,113.00 11.67 173.52 1,109.31 -35.83 32.451,045.80 5,999,849.28 565,511.46 4.28 -41.34 3_Gyro-GC_Csg (1) 1,176.00 14.10 175.00 1,170.72 -49.81 33.841,107.21 5,999,835.31 565,512.97 3.89 -55.33 3_Gyro-GC_Csg (1) 1,240.00 16.05 177.95 1,232.51 -66.42 34.841,169.00 5,999,818.71 565,514.12 3.27 -71.83 3_Gyro-GC_Csg (1) 1,303.00 18.82 177.02 1,292.61 -85.28 35.681,229.10 5,999,799.87 565,515.12 4.42 -90.50 3_Gyro-GC_Csg (1) 1,367.00 21.66 176.11 1,352.65 -107.37 37.021,289.14 5,999,777.79 565,516.65 4.46 -112.45 3_Gyro-GC_Csg (1) 1,430.00 24.19 174.91 1,410.67 -131.83 38.951,347.16 5,999,753.34 565,518.80 4.08 -136.83 3_Gyro-GC_Csg (1) 1,494.00 24.62 173.58 1,468.95 -158.14 41.601,405.44 5,999,727.06 565,521.69 1.09 -163.16 3_Gyro-GC_Csg (1) 1,558.00 26.12 172.41 1,526.78 -185.36 44.961,463.27 5,999,699.88 565,525.28 2.47 -190.52 3_Gyro-GC_Csg (1) 1,621.00 28.86 170.17 1,582.66 -214.09 49.391,519.15 5,999,671.19 565,529.96 4.65 -219.57 3_Gyro-GC_Csg (1) 1,717.59 30.72 168.98 1,666.49 -261.28 58.081,602.98 5,999,624.08 565,539.06 2.02 -267.55 3_MWD+IFR2+MS+Sag (2) 1,780.50 35.40 167.17 1,719.20 -294.84 65.201,655.69 5,999,590.59 565,546.48 7.60 -301.85 3_MWD+IFR2+MS+Sag (2) 1,844.14 38.46 167.20 1,770.06 -332.12 73.681,706.55 5,999,553.39 565,555.28 4.81 -340.07 3_MWD+IFR2+MS+Sag (2) 1,908.08 37.82 167.68 1,820.35 -370.66 82.271,756.84 5,999,514.93 565,564.21 1.10 -379.54 3_MWD+IFR2+MS+Sag (2) 1,971.57 37.57 168.09 1,870.59 -408.62 90.421,807.08 5,999,477.05 565,572.69 0.56 -418.35 3_MWD+IFR2+MS+Sag (2) 2,034.83 37.71 169.09 1,920.68 -446.49 98.061,857.17 5,999,439.25 565,580.66 0.99 -456.98 3_MWD+IFR2+MS+Sag (2) 2,098.63 38.42 169.05 1,970.91 -485.11 105.521,907.40 5,999,400.70 565,588.46 1.11 -496.32 3_MWD+IFR2+MS+Sag (2) 2,162.22 38.74 169.37 2,020.63 -524.06 112.941,957.12 5,999,361.82 565,596.22 0.59 -535.97 3_MWD+IFR2+MS+Sag (2) 2,225.95 40.27 168.27 2,069.80 -563.83 120.812,006.29 5,999,322.12 565,604.44 2.64 -576.51 3_MWD+IFR2+MS+Sag (2) 2,289.34 40.59 167.77 2,118.05 -604.04 129.342,054.54 5,999,281.99 565,613.32 0.72 -617.61 3_MWD+IFR2+MS+Sag (2) 2,350.47 41.31 167.70 2,164.22 -643.19 137.852,100.71 5,999,242.92 565,622.17 1.18 -657.67 3_MWD+IFR2+MS+Sag (2) 2,416.76 41.61 166.22 2,213.90 -685.95 147.762,150.39 5,999,200.26 565,632.45 1.55 -701.53 3_MWD+IFR2+MS+Sag (2) 2,479.97 41.59 167.67 2,261.17 -726.83 157.242,197.66 5,999,159.47 565,642.29 1.52 -743.46 3_MWD+IFR2+MS+Sag (2) 2,544.42 41.48 166.13 2,309.41 -768.45 166.922,245.90 5,999,117.94 565,652.34 1.59 -786.16 3_MWD+IFR2+MS+Sag (2) 2,607.64 40.95 166.45 2,356.97 -808.92 176.802,293.46 5,999,077.56 565,662.56 0.90 -827.77 3_MWD+IFR2+MS+Sag (2) 2,671.64 41.34 167.04 2,405.17 -849.91 186.452,341.66 5,999,036.66 565,672.58 0.86 -869.84 3_MWD+IFR2+MS+Sag (2) 2,735.71 40.55 166.85 2,453.56 -890.81 195.932,390.05 5,998,995.85 565,682.42 1.25 -911.80 3_MWD+IFR2+MS+Sag (2) 2,798.97 40.04 166.96 2,501.81 -930.66 205.202,438.30 5,998,956.09 565,692.03 0.81 -952.69 3_MWD+IFR2+MS+Sag (2) 2,861.88 40.27 167.42 2,549.89 -970.21 214.202,486.38 5,998,916.61 565,701.37 0.60 -993.23 3_MWD+IFR2+MS+Sag (2) 2,925.46 39.66 168.75 2,598.62 -1,010.17 222.632,535.11 5,998,876.74 565,710.16 1.65 -1,034.06 3_MWD+IFR2+MS+Sag (2) 2,989.22 39.03 170.59 2,647.93 -1,049.93 229.882,584.42 5,998,837.04 565,717.76 2.08 -1,074.48 3_MWD+IFR2+MS+Sag (2) 3,051.04 38.61 171.98 2,696.10 -1,088.24 235.762,632.59 5,998,798.80 565,723.97 1.56 -1,113.20 3_MWD+IFR2+MS+Sag (2) 3,115.32 37.50 175.54 2,746.72 -1,127.61 240.082,683.21 5,998,759.47 565,728.63 3.83 -1,152.68 3_MWD+IFR2+MS+Sag (2) 3,178.91 36.20 177.36 2,797.61 -1,165.67 242.452,734.10 5,998,721.43 565,731.33 2.67 -1,190.49 3_MWD+IFR2+MS+Sag (2) 4/13/2020 12:47:00PM COMPASS 5000.15 Build 91E Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-56i MPU S-56PB1 Survey Calculation Method:Minimum Curvature MPU S-56i Actual RKB @ 63.51usft Design:MPU S-56PB1 Database:NORTH US + CANADA MD Reference:MPU S-56i Actual RKB @ 63.51usft North Reference: Well MPU S-56i True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,242.38 33.79 181.10 2,849.60 -1,202.05 242.972,786.09 5,998,685.07 565,732.18 5.08 -1,226.31 3_MWD+IFR2+MS+Sag (2) 3,305.94 33.09 187.24 2,902.66 -1,236.94 240.452,839.15 5,998,650.15 565,729.96 5.43 -1,260.09 3_MWD+IFR2+MS+Sag (2) 3,369.02 32.43 191.36 2,955.71 -1,270.61 234.942,892.20 5,998,616.44 565,724.75 3.69 -1,292.10 3_MWD+IFR2+MS+Sag (2) 3,433.06 32.21 195.62 3,009.83 -1,303.88 226.962,946.32 5,998,583.10 565,717.06 3.57 -1,323.26 3_MWD+IFR2+MS+Sag (2) 3,496.32 31.26 199.87 3,063.64 -1,335.56 216.843,000.13 5,998,551.34 565,707.22 3.84 -1,352.44 3_MWD+IFR2+MS+Sag (2) 3,560.12 31.46 207.32 3,118.14 -1,365.93 203.573,054.63 5,998,520.85 565,694.22 6.08 -1,379.74 3_MWD+IFR2+MS+Sag (2) 3,623.49 34.31 213.65 3,171.37 -1,395.51 186.083,107.86 5,998,491.13 565,676.99 7.04 -1,405.46 3_MWD+IFR2+MS+Sag (2) 3,686.95 35.42 221.09 3,223.46 -1,424.27 164.073,159.95 5,998,462.18 565,655.23 6.92 -1,429.52 3_MWD+IFR2+MS+Sag (2) 3,750.29 35.31 228.31 3,275.14 -1,450.29 138.323,211.63 5,998,435.94 565,629.72 6.60 -1,450.19 3_MWD+IFR2+MS+Sag (2) 3,814.14 35.61 233.40 3,327.16 -1,473.65 109.623,263.65 5,998,412.33 565,601.22 4.65 -1,467.67 3_MWD+IFR2+MS+Sag (2) 3,877.85 35.44 238.85 3,379.02 -1,494.27 78.913,315.51 5,998,391.44 565,570.70 4.98 -1,482.09 3_MWD+IFR2+MS+Sag (2) 3,941.57 35.13 243.85 3,431.04 -1,511.91 46.643,367.53 5,998,373.52 565,538.58 4.56 -1,493.28 3_MWD+IFR2+MS+Sag (2) 4,004.62 36.50 249.19 3,482.18 -1,526.57 12.813,418.67 5,998,358.56 565,504.89 5.41 -1,501.26 3_MWD+IFR2+MS+Sag (2) 4,068.28 39.57 253.03 3,532.33 -1,539.22 -24.293,468.82 5,998,345.59 565,467.90 6.09 -1,506.64 3_MWD+IFR2+MS+Sag (2) 4,131.29 43.15 255.89 3,579.62 -1,550.34 -64.403,516.11 5,998,334.13 565,427.90 6.42 -1,509.94 3_MWD+IFR2+MS+Sag (2) 4,195.20 45.32 259.79 3,625.41 -1,559.69 -107.973,561.90 5,998,324.39 565,384.42 5.44 -1,510.86 3_MWD+IFR2+MS+Sag (2) 4,259.07 46.51 263.40 3,669.86 -1,566.38 -153.343,606.35 5,998,317.30 565,339.11 4.47 -1,508.82 3_MWD+IFR2+MS+Sag (2) 4,321.97 47.74 266.49 3,712.66 -1,570.43 -199.253,649.15 5,998,312.85 565,293.24 4.10 -1,504.08 3_MWD+IFR2+MS+Sag (2) 4,385.56 49.00 269.31 3,754.91 -1,572.16 -246.743,691.40 5,998,310.71 565,245.78 3.86 -1,496.76 3_MWD+IFR2+MS+Sag (2) 4,449.74 50.36 270.93 3,796.43 -1,572.05 -295.673,732.92 5,998,310.39 565,196.85 2.86 -1,487.37 3_MWD+IFR2+MS+Sag (2) 4,513.63 53.02 272.41 3,836.04 -1,570.58 -345.773,772.53 5,998,311.42 565,146.74 4.54 -1,476.42 3_MWD+IFR2+MS+Sag (2) 4,576.73 57.63 274.24 3,871.93 -1,567.55 -397.563,808.42 5,998,314.00 565,094.94 7.68 -1,463.61 3_MWD+IFR2+MS+Sag (2) 4,640.53 60.51 276.30 3,904.72 -1,562.51 -452.043,841.21 5,998,318.56 565,040.41 5.30 -1,448.32 3_MWD+IFR2+MS+Sag (2) 4,704.20 60.30 277.88 3,936.17 -1,555.67 -506.983,872.66 5,998,324.91 564,985.42 2.18 -1,431.19 3_MWD+IFR2+MS+Sag (2) 4,767.65 63.85 281.04 3,965.88 -1,546.44 -562.263,902.37 5,998,333.66 564,930.07 7.12 -1,411.63 3_MWD+IFR2+MS+Sag (2) 4,831.20 68.71 283.65 3,991.44 -1,533.98 -619.063,927.93 5,998,345.62 564,873.17 8.52 -1,388.62 3_MWD+IFR2+MS+Sag (2) 4,894.23 68.17 284.96 4,014.61 -1,519.50 -675.873,951.10 5,998,359.60 564,816.25 2.11 -1,363.62 3_MWD+IFR2+MS+Sag (2) 4,957.54 70.22 286.00 4,037.09 -1,503.70 -732.903,973.58 5,998,374.90 564,759.08 3.58 -1,337.28 3_MWD+IFR2+MS+Sag (2) 5,021.04 76.16 286.63 4,055.45 -1,486.63 -791.213,991.94 5,998,391.46 564,700.63 9.40 -1,309.45 3_MWD+IFR2+MS+Sag (2) 5,085.43 79.07 288.13 4,069.26 -1,467.84 -851.224,005.75 5,998,409.72 564,640.46 5.06 -1,279.62 3_MWD+IFR2+MS+Sag (2) 5,147.91 81.08 290.42 4,080.03 -1,447.52 -909.304,016.52 5,998,429.52 564,582.21 4.84 -1,248.65 3_MWD+IFR2+MS+Sag (2) 5,212.94 83.26 292.50 4,088.89 -1,423.95 -969.254,025.38 5,998,452.56 564,522.06 4.61 -1,214.13 3_MWD+IFR2+MS+Sag (2) 5,276.39 86.73 294.28 4,094.42 -1,398.86 -1,027.254,030.91 5,998,477.14 564,463.85 6.14 -1,178.49 3_MWD+IFR2+MS+Sag (2) 5,308.30 89.14 295.01 4,095.57 -1,385.57 -1,056.244,032.06 5,998,490.18 564,434.75 7.89 -1,159.93 3_MWD+IFR2+MS+Sag (2) 5,384.94 91.11 299.66 4,095.41 -1,350.38 -1,124.304,031.90 5,998,524.76 564,366.39 6.59 -1,112.47 3_MWD+IFR2+MS+Sag (3) 5,449.10 92.72 298.82 4,093.26 -1,319.06 -1,180.254,029.75 5,998,555.59 564,310.17 2.83 -1,071.10 3_MWD+IFR2+MS+Sag (3) 5,513.66 93.15 299.92 4,089.96 -1,287.44 -1,236.434,026.45 5,998,586.71 564,253.72 1.83 -1,029.39 3_MWD+IFR2+MS+Sag (3) 5,577.44 93.21 303.79 4,086.42 -1,253.84 -1,290.514,022.91 5,998,619.84 564,199.35 6.06 -986.14 3_MWD+IFR2+MS+Sag (3) 5,640.56 92.59 306.88 4,083.22 -1,217.38 -1,341.934,019.71 5,998,655.84 564,147.62 4.99 -940.59 3_MWD+IFR2+MS+Sag (3) 5,704.46 92.09 308.39 4,080.61 -1,178.40 -1,392.494,017.10 5,998,694.37 564,096.72 2.49 -892.71 3_MWD+IFR2+MS+Sag (3) 4/13/2020 12:47:00PM COMPASS 5000.15 Build 91E Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-56i MPU S-56PB1 Survey Calculation Method:Minimum Curvature MPU S-56i Actual RKB @ 63.51usft Design:MPU S-56PB1 Database:NORTH US + CANADA MD Reference:MPU S-56i Actual RKB @ 63.51usft North Reference: Well MPU S-56i True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,768.44 91.91 310.28 4,078.38 -1,137.87 -1,441.954,014.87 5,998,734.46 564,046.92 2.97 -843.54 3_MWD+IFR2+MS+Sag (3) 5,832.08 91.60 311.49 4,076.43 -1,096.24 -1,490.044,012.92 5,998,775.67 563,998.47 1.96 -793.53 3_MWD+IFR2+MS+Sag (3) 5,895.99 91.60 312.27 4,074.65 -1,053.59 -1,537.604,011.14 5,998,817.89 563,950.54 1.22 -742.63 3_MWD+IFR2+MS+Sag (3) 5,959.09 92.72 313.32 4,072.27 -1,010.75 -1,583.874,008.76 5,998,860.32 563,903.90 2.43 -691.79 3_MWD+IFR2+MS+Sag (3) 6,023.41 93.08 314.89 4,069.01 -966.05 -1,630.004,005.50 5,998,904.61 563,857.39 2.50 -639.15 3_MWD+IFR2+MS+Sag (3) 6,087.13 93.02 315.50 4,065.62 -920.90 -1,674.834,002.11 5,998,949.36 563,812.16 0.96 -586.31 3_MWD+IFR2+MS+Sag (3) 6,150.46 92.78 317.02 4,062.42 -875.20 -1,718.563,998.91 5,998,994.67 563,768.04 2.43 -533.15 3_MWD+IFR2+MS+Sag (3) 6,214.29 93.09 319.72 4,059.15 -827.56 -1,760.913,995.64 5,999,041.93 563,725.28 4.25 -478.34 3_MWD+IFR2+MS+Sag (3) 6,278.18 92.53 320.01 4,056.02 -778.78 -1,802.043,992.51 5,999,090.35 563,683.73 0.99 -422.63 3_MWD+IFR2+MS+Sag (3) 6,341.23 91.60 321.65 4,053.75 -729.93 -1,841.843,990.24 5,999,138.84 563,643.51 2.99 -367.12 3_MWD+IFR2+MS+Sag (3) 6,404.77 90.24 322.74 4,052.73 -679.73 -1,880.783,989.22 5,999,188.69 563,604.13 2.74 -310.44 3_MWD+IFR2+MS+Sag (3) 6,467.05 89.57 322.88 4,052.83 -630.12 -1,918.423,989.32 5,999,237.97 563,566.06 1.10 -254.59 3_MWD+IFR2+MS+Sag (3) 6,531.20 90.06 323.71 4,053.04 -578.69 -1,956.763,989.53 5,999,289.05 563,527.27 1.50 -196.82 3_MWD+IFR2+MS+Sag (3) 6,595.52 89.94 325.15 4,053.04 -526.37 -1,994.183,989.53 5,999,341.04 563,489.40 2.25 -138.35 3_MWD+IFR2+MS+Sag (3) 6,659.00 90.62 326.97 4,052.73 -473.71 -2,029.623,989.22 5,999,393.38 563,453.51 3.06 -79.92 3_MWD+IFR2+MS+Sag (3) 6,722.47 89.94 329.00 4,052.42 -419.90 -2,063.263,988.91 5,999,446.89 563,419.39 3.37 -20.70 3_MWD+IFR2+MS+Sag (3) 6,786.24 89.38 329.32 4,052.79 -365.15 -2,095.953,989.28 5,999,501.35 563,386.23 1.01 39.26 3_MWD+IFR2+MS+Sag (3) 6,850.19 88.45 330.14 4,054.00 -309.93 -2,128.183,990.49 5,999,556.28 563,353.52 1.94 99.59 3_MWD+IFR2+MS+Sag (3) 6,913.85 87.77 330.74 4,056.10 -254.58 -2,159.573,992.59 5,999,611.34 563,321.65 1.42 159.89 3_MWD+IFR2+MS+Sag (3) 6,977.64 86.91 332.70 4,059.06 -198.47 -2,189.763,995.55 5,999,667.18 563,290.97 3.35 220.71 3_MWD+IFR2+MS+Sag (3) 7,041.57 86.79 334.66 4,062.58 -141.26 -2,218.063,999.07 5,999,724.14 563,262.17 3.07 282.26 3_MWD+IFR2+MS+Sag (3) 7,105.18 87.59 336.47 4,065.70 -83.42 -2,244.344,002.19 5,999,781.74 563,235.39 3.11 344.03 3_MWD+IFR2+MS+Sag (3) 7,168.60 89.52 336.32 4,067.30 -25.33 -2,269.734,003.79 5,999,839.60 563,209.50 3.05 405.89 3_MWD+IFR2+MS+Sag (3) 7,232.21 91.12 336.67 4,066.94 33.00 -2,295.104,003.43 5,999,897.70 563,183.62 2.57 467.97 3_MWD+IFR2+MS+Sag (3) 7,295.90 90.37 335.47 4,066.11 91.21 -2,320.934,002.60 5,999,955.67 563,157.28 2.22 530.02 3_MWD+IFR2+MS+Sag (3) 7,359.56 90.74 335.55 4,065.50 149.14 -2,347.324,001.99 6,000,013.37 563,130.39 0.59 591.91 3_MWD+IFR2+MS+Sag (3) 7,422.77 90.68 334.60 4,064.71 206.46 -2,373.954,001.20 6,000,070.44 563,103.26 1.51 653.24 3_MWD+IFR2+MS+Sag (3) 7,486.59 90.43 333.96 4,064.09 263.95 -2,401.654,000.58 6,000,127.69 563,075.06 1.08 714.94 3_MWD+IFR2+MS+Sag (3) 7,550.09 92.53 333.21 4,062.45 320.80 -2,429.883,998.94 6,000,184.28 563,046.33 3.51 776.12 3_MWD+IFR2+MS+Sag (3) 7,613.76 94.08 335.14 4,058.78 378.01 -2,457.573,995.27 6,000,241.24 563,018.14 3.88 837.54 3_MWD+IFR2+MS+Sag (3) 7,677.39 93.76 338.23 4,054.43 436.30 -2,482.693,990.92 6,000,299.30 562,992.51 4.87 899.54 3_MWD+IFR2+MS+Sag (3) 7,740.85 93.21 341.47 4,050.57 495.76 -2,504.513,987.06 6,000,358.56 562,970.18 5.17 962.06 3_MWD+IFR2+MS+Sag (3) 7,804.16 91.97 344.64 4,047.71 556.25 -2,522.943,984.20 6,000,418.88 562,951.22 5.37 1,024.95 3_MWD+IFR2+MS+Sag (3) 7,867.66 91.36 347.89 4,045.87 617.90 -2,538.013,982.36 6,000,480.39 562,935.61 5.21 1,088.34 3_MWD+IFR2+MS+Sag (3) 7,928.70 91.11 351.39 4,044.55 677.92 -2,548.983,981.04 6,000,540.31 562,924.12 5.75 1,149.35 3_MWD+IFR2+MS+Sag (3) 7,994.43 91.05 353.14 4,043.31 743.04 -2,557.833,979.80 6,000,605.34 562,914.70 2.66 1,214.96 3_MWD+IFR2+MS+Sag (3) 8,057.90 91.42 353.39 4,041.94 806.06 -2,565.273,978.43 6,000,668.28 562,906.71 0.70 1,278.25 3_MWD+IFR2+MS+Sag (3) 8,121.52 91.91 353.54 4,040.10 869.24 -2,572.513,976.59 6,000,731.39 562,898.92 0.81 1,341.65 3_MWD+IFR2+MS+Sag (3) 8,184.92 92.10 354.90 4,037.88 932.28 -2,578.893,974.37 6,000,794.36 562,891.99 2.16 1,404.76 3_MWD+IFR2+MS+Sag (3) 8,248.76 92.10 354.93 4,035.54 995.82 -2,584.543,972.03 6,000,857.85 562,885.77 0.05 1,468.22 3_MWD+IFR2+MS+Sag (3) 4/13/2020 12:47:00PM COMPASS 5000.15 Build 91E Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-56i MPU S-56PB1 Survey Calculation Method:Minimum Curvature MPU S-56i Actual RKB @ 63.51usft Design:MPU S-56PB1 Database:NORTH US + CANADA MD Reference:MPU S-56i Actual RKB @ 63.51usft North Reference: Well MPU S-56i True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,312.38 91.48 355.29 4,033.55 1,059.18 -2,589.963,970.04 6,000,921.15 562,879.80 1.13 1,531.45 3_MWD+IFR2+MS+Sag (3) 8,376.16 89.07 354.19 4,033.24 1,122.68 -2,595.813,969.73 6,000,984.60 562,873.40 4.15 1,594.92 3_MWD+IFR2+MS+Sag (3) 8,439.56 88.39 353.24 4,034.65 1,185.69 -2,602.753,971.14 6,001,047.53 562,865.91 1.84 1,658.09 3_MWD+IFR2+MS+Sag (3) 8,503.16 88.83 349.92 4,036.19 1,248.57 -2,612.063,972.68 6,001,110.33 562,856.05 5.26 1,721.60 3_MWD+IFR2+MS+Sag (3) 8,567.03 89.01 348.10 4,037.40 1,311.26 -2,624.233,973.89 6,001,172.90 562,843.33 2.86 1,785.46 3_MWD+IFR2+MS+Sag (3) 8,629.45 88.89 348.39 4,038.54 1,372.36 -2,636.943,975.03 6,001,233.88 562,830.08 0.50 1,847.86 3_MWD+IFR2+MS+Sag (3) 8,692.48 88.40 349.11 4,040.03 1,434.16 -2,649.243,976.52 6,001,295.56 562,817.24 1.38 1,910.87 3_MWD+IFR2+MS+Sag (3) 8,756.20 88.46 349.75 4,041.78 1,496.77 -2,660.923,978.27 6,001,358.07 562,805.01 1.01 1,974.56 3_MWD+IFR2+MS+Sag (3) 8,819.38 88.77 350.97 4,043.30 1,559.04 -2,671.503,979.79 6,001,420.24 562,793.89 1.99 2,037.71 3_MWD+IFR2+MS+Sag (3) 8,882.30 87.77 350.54 4,045.20 1,621.12 -2,681.603,981.69 6,001,482.21 562,783.25 1.73 2,100.57 3_MWD+IFR2+MS+Sag (3) 8,946.46 88.40 350.07 4,047.35 1,684.32 -2,692.403,983.84 6,001,545.32 562,771.89 1.22 2,164.68 3_MWD+IFR2+MS+Sag (3) 9,009.97 88.71 349.54 4,048.95 1,746.81 -2,703.643,985.44 6,001,607.70 562,760.11 0.97 2,228.16 3_MWD+IFR2+MS+Sag (3) 9,073.86 88.52 348.44 4,050.49 1,809.51 -2,715.843,986.98 6,001,670.28 562,747.36 1.75 2,292.03 3_MWD+IFR2+MS+Sag (3) 9,137.81 88.46 348.74 4,052.18 1,872.17 -2,728.483,988.67 6,001,732.82 562,734.17 0.48 2,355.96 3_MWD+IFR2+MS+Sag (3) 9,201.71 89.08 349.70 4,053.55 1,934.93 -2,740.433,990.04 6,001,795.47 562,721.67 1.79 2,419.84 3_MWD+IFR2+MS+Sag (3) 9,265.11 88.52 350.24 4,054.88 1,997.34 -2,751.473,991.37 6,001,857.78 562,710.09 1.23 2,483.22 3_MWD+IFR2+MS+Sag (3) 9,328.58 88.89 349.96 4,056.31 2,059.85 -2,762.383,992.80 6,001,920.18 562,698.63 0.73 2,546.66 3_MWD+IFR2+MS+Sag (3) 9,392.82 88.64 349.45 4,057.70 2,123.04 -2,773.863,994.19 6,001,983.26 562,686.60 0.88 2,610.89 3_MWD+IFR2+MS+Sag (3) 9,456.05 88.83 349.20 4,059.09 2,185.16 -2,785.573,995.58 6,002,045.27 562,674.35 0.50 2,674.10 3_MWD+IFR2+MS+Sag (3) 9,519.93 89.82 349.37 4,059.85 2,247.92 -2,797.443,996.34 6,002,107.92 562,661.92 1.57 2,737.97 3_MWD+IFR2+MS+Sag (3) 9,583.64 90.99 349.93 4,059.40 2,310.60 -2,808.893,995.89 6,002,170.48 562,649.93 2.04 2,801.68 3_MWD+IFR2+MS+Sag (3) 9,647.18 91.24 349.98 4,058.16 2,373.15 -2,819.973,994.65 6,002,232.93 562,638.30 0.40 2,865.20 3_MWD+IFR2+MS+Sag (3) 9,711.09 91.98 348.64 4,056.36 2,435.92 -2,831.823,992.85 6,002,295.59 562,625.90 2.39 2,929.08 3_MWD+IFR2+MS+Sag (3) 9,774.47 92.10 348.02 4,054.11 2,497.95 -2,844.633,990.60 6,002,357.50 562,612.55 1.00 2,992.41 3_MWD+IFR2+MS+Sag (3) 9,837.95 90.74 346.80 4,052.53 2,559.89 -2,858.463,989.02 6,002,419.31 562,598.18 2.88 3,055.85 3_MWD+IFR2+MS+Sag (3) 9,901.25 91.42 348.03 4,051.34 2,621.65 -2,872.253,987.83 6,002,480.94 562,583.85 2.22 3,119.11 3_MWD+IFR2+MS+Sag (3) 9,965.07 90.86 348.89 4,050.07 2,684.17 -2,885.023,986.56 6,002,543.34 562,570.54 1.61 3,182.91 3_MWD+IFR2+MS+Sag (3) 10,028.88 91.30 348.96 4,048.87 2,746.78 -2,897.273,985.36 6,002,605.83 562,557.73 0.70 3,246.71 3_MWD+IFR2+MS+Sag (3) 10,092.06 90.93 350.08 4,047.64 2,808.89 -2,908.763,984.13 6,002,667.84 562,545.70 1.87 3,309.87 3_MWD+IFR2+MS+Sag (3) 10,155.97 90.25 350.52 4,046.98 2,871.88 -2,919.533,983.47 6,002,730.73 562,534.38 1.27 3,373.76 3_MWD+IFR2+MS+Sag (3) 10,219.77 90.00 350.81 4,046.84 2,934.84 -2,929.883,983.33 6,002,793.58 562,523.48 0.60 3,437.54 3_MWD+IFR2+MS+Sag (3) 10,282.88 90.12 351.12 4,046.78 2,997.17 -2,939.793,983.27 6,002,855.82 562,513.03 0.53 3,500.61 3_MWD+IFR2+MS+Sag (3) 10,346.87 89.57 350.09 4,046.95 3,060.30 -2,950.243,983.44 6,002,918.85 562,502.03 1.82 3,564.58 3_MWD+IFR2+MS+Sag (3) 10,410.21 88.76 347.86 4,047.87 3,122.46 -2,962.353,984.36 6,002,980.89 562,489.38 3.75 3,627.91 3_MWD+IFR2+MS+Sag (3) 10,474.10 89.20 348.63 4,049.01 3,185.00 -2,975.363,985.50 6,003,043.31 562,475.82 1.39 3,691.78 3_MWD+IFR2+MS+Sag (3) 10,537.87 88.70 348.05 4,050.18 3,247.44 -2,988.253,986.67 6,003,105.63 562,462.39 1.20 3,755.53 3_MWD+IFR2+MS+Sag (3) 10,601.31 89.14 349.10 4,051.37 3,309.61 -3,000.813,987.86 6,003,167.68 562,449.28 1.79 3,818.96 3_MWD+IFR2+MS+Sag (3) 10,664.60 88.83 348.96 4,052.49 3,371.73 -3,012.853,988.98 6,003,229.69 562,436.69 0.54 3,882.24 3_MWD+IFR2+MS+Sag (3) 10,728.18 89.01 348.98 4,053.69 3,434.13 -3,025.013,990.18 6,003,291.97 562,423.99 0.28 3,945.81 3_MWD+IFR2+MS+Sag (3) 10,791.72 88.83 350.08 4,054.89 3,496.60 -3,036.563,991.38 6,003,354.33 562,411.90 1.75 4,009.33 3_MWD+IFR2+MS+Sag (3) 4/13/2020 12:47:00PM COMPASS 5000.15 Build 91E Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-56i MPU S-56PB1 Survey Calculation Method:Minimum Curvature MPU S-56i Actual RKB @ 63.51usft Design:MPU S-56PB1 Database:NORTH US + CANADA MD Reference:MPU S-56i Actual RKB @ 63.51usft North Reference: Well MPU S-56i True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,856.10 89.14 350.62 4,056.03 3,560.06 -3,047.353,992.52 6,003,417.69 562,400.55 0.97 4,073.69 3_MWD+IFR2+MS+Sag (3) 10,919.37 88.46 351.16 4,057.36 3,622.51 -3,057.363,993.85 6,003,480.05 562,389.99 1.37 4,136.91 3_MWD+IFR2+MS+Sag (3) 10,982.68 88.64 350.97 4,058.96 3,685.04 -3,067.193,995.45 6,003,542.48 562,379.61 0.41 4,200.16 3_MWD+IFR2+MS+Sag (3) 11,046.11 88.33 350.87 4,060.64 3,747.65 -3,077.203,997.13 6,003,604.99 562,369.06 0.51 4,263.54 3_MWD+IFR2+MS+Sag (3) 11,109.38 89.88 351.26 4,061.62 3,810.14 -3,087.023,998.11 6,003,667.39 562,358.69 2.53 4,326.76 3_MWD+IFR2+MS+Sag (3) 11,173.29 91.24 351.39 4,061.00 3,873.32 -3,096.663,997.49 6,003,730.47 562,348.50 2.14 4,390.61 3_MWD+IFR2+MS+Sag (3) 11,236.77 91.55 351.04 4,059.45 3,936.03 -3,106.363,995.94 6,003,793.10 562,338.25 0.74 4,454.03 3_MWD+IFR2+MS+Sag (3) 11,300.57 92.66 350.53 4,057.11 3,998.97 -3,116.573,993.60 6,003,855.93 562,327.49 1.91 4,517.76 3_MWD+IFR2+MS+Sag (3) 11,364.87 92.84 349.50 4,054.02 4,062.22 -3,127.703,990.51 6,003,919.08 562,315.81 1.62 4,581.97 3_MWD+IFR2+MS+Sag (3) 11,427.88 92.09 348.66 4,051.31 4,124.03 -3,139.633,987.80 6,003,980.78 562,303.34 1.79 4,644.92 3_MWD+IFR2+MS+Sag (3) 11,491.54 91.23 347.98 4,049.47 4,186.34 -3,152.513,985.96 6,004,042.97 562,289.91 1.72 4,708.55 3_MWD+IFR2+MS+Sag (3) 11,554.74 91.30 348.22 4,048.08 4,248.17 -3,165.543,984.57 6,004,104.67 562,276.34 0.40 4,771.72 3_MWD+IFR2+MS+Sag (3) 11,617.92 91.11 348.20 4,046.75 4,310.00 -3,178.443,983.24 6,004,166.39 562,262.90 0.30 4,834.88 3_MWD+IFR2+MS+Sag (3) 11,680.67 91.05 348.66 4,045.56 4,371.47 -3,191.033,982.05 6,004,227.73 562,249.78 0.74 4,897.62 3_MWD+IFR2+MS+Sag (3) 11,744.23 90.31 349.33 4,044.81 4,433.85 -3,203.163,981.30 6,004,290.00 562,237.10 1.57 4,961.17 3_MWD+IFR2+MS+Sag (3) 11,807.92 90.74 349.08 4,044.23 4,496.41 -3,215.093,980.72 6,004,352.45 562,224.62 0.78 5,024.86 3_MWD+IFR2+MS+Sag (3) 11,871.37 90.49 349.29 4,043.55 4,558.73 -3,226.993,980.04 6,004,414.66 562,212.18 0.51 5,088.31 3_MWD+IFR2+MS+Sag (3) 11,935.31 91.18 349.39 4,042.61 4,621.56 -3,238.823,979.10 6,004,477.37 562,199.80 1.09 5,152.24 3_MWD+IFR2+MS+Sag (3) 11,998.70 91.11 349.51 4,041.35 4,683.87 -3,250.423,977.84 6,004,539.57 562,187.65 0.22 5,215.61 3_MWD+IFR2+MS+Sag (3) 12,062.21 91.05 349.17 4,040.15 4,746.27 -3,262.173,976.64 6,004,601.86 562,175.36 0.54 5,279.11 3_MWD+IFR2+MS+Sag (3) 12,125.71 90.12 349.43 4,039.50 4,808.66 -3,273.963,975.99 6,004,664.14 562,163.03 1.52 5,342.61 3_MWD+IFR2+MS+Sag (3) 12,189.33 90.25 348.50 4,039.30 4,871.11 -3,286.143,975.79 6,004,726.47 562,150.30 1.48 5,406.23 3_MWD+IFR2+MS+Sag (3) 12,252.82 90.31 348.98 4,038.99 4,933.37 -3,298.533,975.48 6,004,788.62 562,137.36 0.76 5,469.71 3_MWD+IFR2+MS+Sag (3) 12,316.33 91.42 348.71 4,038.03 4,995.67 -3,310.823,974.52 6,004,850.80 562,124.53 1.80 5,533.22 3_MWD+IFR2+MS+Sag (3) 12,379.97 92.04 348.58 4,036.11 5,058.04 -3,323.343,972.60 6,004,913.05 562,111.46 1.00 5,596.82 3_MWD+IFR2+MS+Sag (3) 12,443.56 92.41 348.62 4,033.64 5,120.33 -3,335.903,970.13 6,004,975.22 562,098.36 0.59 5,660.36 3_MWD+IFR2+MS+Sag (3) 12,507.29 91.91 348.03 4,031.23 5,182.70 -3,348.793,967.72 6,005,037.47 562,084.93 1.21 5,724.04 3_MWD+IFR2+MS+Sag (3) 12,570.65 91.61 348.41 4,029.29 5,244.69 -3,361.723,965.78 6,005,099.34 562,071.46 0.76 5,787.37 3_MWD+IFR2+MS+Sag (3) 12,634.23 90.55 348.81 4,028.09 5,307.01 -3,374.273,964.58 6,005,161.54 562,058.36 1.78 5,850.93 3_MWD+IFR2+MS+Sag (3) 12,697.75 90.81 349.38 4,027.34 5,369.38 -3,386.293,963.83 6,005,223.79 562,045.80 0.99 5,914.45 3_MWD+IFR2+MS+Sag (3) 12,760.90 91.42 350.35 4,026.11 5,431.53 -3,397.403,962.60 6,005,285.84 562,034.14 1.81 5,977.58 3_MWD+IFR2+MS+Sag (3) 12,824.40 91.79 349.05 4,024.33 5,493.98 -3,408.753,960.82 6,005,348.18 562,022.25 2.13 6,041.05 3_MWD+IFR2+MS+Sag (3) 12,888.00 89.13 347.02 4,023.82 5,556.19 -3,421.933,960.31 6,005,410.27 562,008.52 5.26 6,104.63 3_MWD+IFR2+MS+Sag (3) 12,950.96 87.47 346.70 4,025.69 5,617.47 -3,436.243,962.18 6,005,471.41 561,993.68 2.69 6,167.51 3_MWD+IFR2+MS+Sag (3) 13,014.85 88.15 347.30 4,028.13 5,679.67 -3,450.603,964.62 6,005,533.49 561,978.77 1.42 6,231.31 3_MWD+IFR2+MS+Sag (3) 13,078.55 88.15 347.22 4,030.18 5,741.77 -3,464.643,966.67 6,005,595.46 561,964.19 0.13 6,294.95 3_MWD+IFR2+MS+Sag (3) 13,142.11 87.71 347.70 4,032.48 5,803.78 -3,478.433,968.97 6,005,657.33 561,949.86 1.02 6,358.44 3_MWD+IFR2+MS+Sag (3) 13,206.18 88.83 349.05 4,034.41 5,866.50 -3,491.333,970.90 6,005,719.93 561,936.41 2.74 6,422.47 3_MWD+IFR2+MS+Sag (3) 13,269.93 89.01 349.75 4,035.62 5,929.15 -3,503.063,972.11 6,005,782.47 561,924.13 1.13 6,486.21 3_MWD+IFR2+MS+Sag (3) 13,333.85 89.07 350.19 4,036.69 5,992.09 -3,514.193,973.18 6,005,845.30 561,912.45 0.69 6,550.11 3_MWD+IFR2+MS+Sag (3) 4/13/2020 12:47:00PM COMPASS 5000.15 Build 91E Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Alaska, LLC Milne Point M Pt S Pad Halliburton Definitive Survey Report Well: Wellbore: MPU S-56i MPU S-56PB1 Survey Calculation Method:Minimum Curvature MPU S-56i Actual RKB @ 63.51usft Design:MPU S-56PB1 Database:NORTH US + CANADA MD Reference:MPU S-56i Actual RKB @ 63.51usft North Reference: Well MPU S-56i True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 13,397.22 88.70 350.81 4,037.92 6,054.57 -3,524.653,974.41 6,005,907.69 561,901.45 1.14 6,613.45 3_MWD+IFR2+MS+Sag (3) 13,460.59 89.14 350.82 4,039.11 6,117.12 -3,534.763,975.60 6,005,970.14 561,890.79 0.69 6,676.78 3_MWD+IFR2+MS+Sag (3) 13,524.35 89.13 350.40 4,040.08 6,180.02 -3,545.163,976.57 6,006,032.94 561,879.84 0.66 6,740.51 3_MWD+IFR2+MS+Sag (3) 13,588.14 90.56 350.13 4,040.25 6,242.89 -3,555.953,976.74 6,006,095.70 561,868.50 2.28 6,804.28 3_MWD+IFR2+MS+Sag (3) 13,650.91 90.56 349.32 4,039.64 6,304.65 -3,567.143,976.13 6,006,157.36 561,856.77 1.29 6,867.05 3_MWD+IFR2+MS+Sag (3) 13,714.48 91.18 349.01 4,038.67 6,367.08 -3,579.093,975.16 6,006,219.67 561,844.27 1.09 6,930.61 3_MWD+IFR2+MS+Sag (3) 13,778.25 90.80 349.31 4,037.57 6,429.70 -3,591.083,974.06 6,006,282.18 561,831.73 0.76 6,994.37 3_MWD+IFR2+MS+Sag (3) 13,841.82 90.99 349.71 4,036.58 6,492.20 -3,602.653,973.07 6,006,344.57 561,819.62 0.70 7,057.93 3_MWD+IFR2+MS+Sag (3) 13,905.56 91.05 349.65 4,035.44 6,554.90 -3,614.073,971.93 6,006,407.16 561,807.65 0.13 7,121.65 3_MWD+IFR2+MS+Sag (3) 13,969.20 90.30 348.81 4,034.69 6,617.41 -3,625.963,971.18 6,006,469.56 561,795.21 1.77 7,185.29 3_MWD+IFR2+MS+Sag (3) 14,033.11 91.55 348.27 4,033.66 6,680.04 -3,638.663,970.15 6,006,532.07 561,781.97 2.13 7,249.19 3_MWD+IFR2+MS+Sag (3) 14,096.75 91.42 348.00 4,032.01 6,742.30 -3,651.743,968.50 6,006,594.21 561,768.34 0.47 7,312.80 3_MWD+IFR2+MS+Sag (3) 14,160.58 91.98 348.02 4,030.12 6,804.71 -3,664.993,966.61 6,006,656.49 561,754.55 0.88 7,376.59 3_MWD+IFR2+MS+Sag (3) 14,223.53 91.85 346.69 4,028.01 6,866.10 -3,678.773,964.50 6,006,717.75 561,740.24 2.12 7,439.47 3_MWD+IFR2+MS+Sag (3) 14,287.43 92.03 346.58 4,025.85 6,928.23 -3,693.533,962.34 6,006,779.75 561,724.93 0.33 7,503.28 3_MWD+IFR2+MS+Sag (3) 14,351.56 92.47 346.47 4,023.33 6,990.55 -3,708.463,959.82 6,006,841.92 561,709.46 0.71 7,567.30 3_MWD+IFR2+MS+Sag (3) 14,414.43 90.49 347.85 4,021.71 7,051.82 -3,722.433,958.20 6,006,903.07 561,694.95 3.84 7,630.11 3_MWD+IFR2+MS+Sag (3) 14,430.60 89.93 347.57 4,021.65 7,067.62 -3,725.873,958.14 6,006,918.83 561,691.37 3.87 7,646.27 3_MWD+IFR2+MS+Sag (3) 14,500.00 89.93 347.57 4,021.73 7,135.39 -3,740.813,958.22 6,006,986.47 561,675.84 0.00 7,715.65 PROJECTED to TD Approved By:Checked By:Date: 4/13/2020 12:47:00PM COMPASS 5000.15 Build 91E Page 8 Chelsea Wright Digitally signed by Chelsea Wright Date: 2020.04.13 09:52:50 -08'00'Benjamin Hand Digitally signed by Benjamin Hand Date: 2020.04.13 11:49:26 -08'00' TD Shoe Depth: PBTD: No. Jts. Returned Jts. 2 1 78 53 X Yes No X Yes No 30 Fluid Description: Liner hanger Info (Make/Model): Liner top Packer?: Yes No Liner hanger test pressure:X Yes No Centralizer Placement: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Tail Slurry Type:Sacks: Yield: Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm): Post Flush (Spacer) Type: Density (ppg)Rate (bpm):Volume: Displacement: Type: Density (ppg) Rate (bpm): Volume (actual / calculated): FCP (psi): Pump used for disp: X Yes No Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped: Cmt returned to surface: Calculated cement left in wellbore: OH volume Calculated: OH volume actual: Actual % Washout: 1.17 3/22/2020 27 Spud Mud Type I/II 418 2.35 Class G 418 1.16 5 2,126.55 Casing 9 5/8 40.0 L-80 TXP Tenaris 2,091.55 2,126.55 35.00 2,145.75 2,142.94 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 16.39 2,142.94 17.10 2,162.85 2,145.75 ES Cementer 10 3/4 40.0 TXP HES 2.81 Pup Joint 9 5/8 40.0 L-80 TXP Tenaris 5,241.72 Casing 9 5/8 40.0 L-80 TXP Tenaris 3,078.87 5,241.72 2,162.85 5,282.82 5,243.19 Baffle Adapter 10 3/4 TXP HES 1.47 5,243.19 1.30 5,284.12 8,282.82 Casing 9 5/8 40.0 L-80 TXP Tenaris 39.63 Float 10 3/4 BTC Innovex (2) on shoe joint (1) every joint from 5363' to 4096' (1) every other joint from 4096' to 2989' (1) every joint from 2355' to 1929' (5 joints before and after ES cementer) (1) ever other joint from 1929' to 115' Casing 9 5/8 40.0 L-80 TXP Tenaris 77.28 5,361.40 5,284.12 www.wellez.net WellEz Information Management LLC ver_04818br 6 208.4Water 4 No. Jts. Delivered 153 No. Jts. Run 135 18 Type of Shoe:Conventional Casing Crew:Weatherford 12 175 Water ES Cementer Closure OK 6208.34 56 Perm L Type Class G 270 Tuned Spacer 136 4.41 Stage Collar @ 50 Bump press 100 236 5,363.005,373.00 CEMENTING REPORT Csg Wt. On Slips:125 Spud Mud 4:43 3/22/2020 2,142 2142.94 15.8 86 Bump press Returns Bump Plug? Yes 3.4 9.1 3 140/143 375.9/377.9 1215 15 RigFIRST STAGE10Tuned Spacer 57 15.8 550 9.3 3 1566 10 10.7 107 5 100 710 Bump Plug? Csg Wt. On Hook:240 Type Float Collar:Conventional No. Hrs to Run:15.5 9 5/8 40.0 L-80 TXP Tenaris BTC Innovex 1.60 5,363.00 5,361.40 10.38 35.00 Setting Depths Component Size Wt.Grade THD Make Length Bottom Top Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No.MP S-56 Date Run 21-Mar-20 CASING RECORD County North Slope Borough State AK Supv.J. Lott/ C Montague 5,282.82 Floats Held 332.17 665 251 414 Spud Mud Rotate Csg Recip Csg Ft. Min.PPG9.3 Shoe @ 5363 FC @ Top of Liner #N/A SECOND STAGERig 21:59 Returns 293.17 375 28 Casing (Or Liner) Detail Shoe Cut Joint 10 3/4 40.0 L-80 CASING AND LEAK-OFF FRACTURE TESTS Well Name:MMPU S-56 Date:3/24/2020 Csg Size/Wt/Grade:9.625 40#L -80 Supervisor:L o t t /Mo n t ag u e Csg Setting Depth:5,363 4,094 TVD Mud Weight:8.9 ppg LOT / FIT Press =660 psi LOT / FIT =12.00 p p g Hole Depth =5393 md Fluid Pumped=1.1 Bbls Volume Back =0.7 bbls Estimated Pump Output:0.062 Barrels/Stroke LOT / FIT DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Her e HHer e Her e HHer e ->233 ->00 ->475 ->10 442 ->6 129 ->15 692 ->8 189 ->20 890 ->10 252 ->25 1079 ->12 317 ->30 1268 ->14 381 ->35 1450 ->16 445 ->40 1624 ->18 509 ->45 1770 ->20 571 ->50 1950 ->22 633 ->55 2140 ->24 707 ->60 2372 ->->65 2567 ->->70 2741 Enter Holding Enter Holding Enter Holding Time Here Pressure Here Time Here Pressure Here ->0 707 ->0 2741 ->0.5 690 ->5 2734 ->1 676 ->10 2730 ->1.5 664 ->15 2728 ->2 649 ->20 2727 ->3 634 ->25 2724 ->4 625 ->30 2724 ->5 617 ->` ->6 608 -> ->7 602 -> ->8 595 -> ->9 589 -> ->10 583 -> ->-> 2 4 6 8 10 12 14 16 18 20 22 24 0 10 15 20 25 30 35 40 45 50 55 60 65 70 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 1020304050607080Pressure (psi)Strokes (# of) LOT / FIT DATA CASING TEST DATA 707690676664649634625617608602595589583 2741273427302728272727242724 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 0 5 10 15 20 25 30Pressure (psi)Time (Minutes) LOT / FIT DATA CASING TEST DATA 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,500'5,400' Casing Collapse Structural Conductor N/A Surface 3090 psi Intermediate Production Liner (FISH)8540 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Yes Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 4/13/2020 11,086'5,686' N/A 4,061' N/A Perforation Depth MD (ft): N/A 4-1/2" 20" 9-5/8" 107' 5,363' N/A 5750 psi 107' 4,088' 107' 5,363' N/A TVD Burst N/A MD 50-029-23669-00-00 Hilcorp Alaska, LLC Length Size Milne Point Unit / Schrader Bluff Oil Pool MPU S-56 Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380109 220-017 3800 Centerpoint Drive, Suite 1400, Acnhorage, AK 99503 COMMISSION USE ONLY 9020 psi Guy Schwartz 4/11/2020 Tubing Grade:Tubing MD (ft): N/A N/A Authorized Title: Drilling Manager Authorized Name: Monty Myers Joe Engel jengel@hilcorp.com 777-8395 4,021'14,500'4,021'1381 N/A m n s 66 t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2020.04.13 15:45:02 -08'00' Monty M Myers 4.13.2020 By Samantha Carlisle at 5:17 pm, Apr 13, 2020 320-163 Suspended gls 4/14/20 DSR=4/13/2020 10-407 X X -- *3500 psi BOPE test * Suspended well inspection required within 1 yr per 20 AAC 25.110(e) DLB 4/14/2020 ed? Yes No Comm. Sr Pe 2020 Approved a XX 4/14/2020 dts 4/14/2020 JLC 4/14/2020 Suspend Procedure Well: MPU S-56 Date: 4/13/2020 Well Name: MPU S-56 API Number: 50-029-23669-00-00 Current Status: Estimated Start Date: 4/13/2020 Rig: Innovation Reg. Approval Req’d? Yes 10-403: Suspend Date Reg. Approval Rec’vd: 4/11/2020 Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 220-017 First Call Engineer: Joe Engel (907) 777-8395 (O) (805)235-6265 (M) Brief Well Summary: S-56 lateral was drilled as per plan. While running in the hole with 4-1/2” liner, the liner hanger inadvertently set at ~ 1780’ MD, due to incorrect assembly from vendor. Attempts to jar the liner hanger free were unsuccessful. The liner top packer and hanger were milled up, and the liner cut at ~ 4500’ MD and pulled from the well. Attempts to fish the remaining liner free were unsuccessful. Hilcorp requests permission to plug back the lateral, with top of fish at 5,400’ MD, and suspend the well. Notes Regarding Wellbore: x 9-5/8” Shoe: 5,363’ MD, 4,095’ TVD x 4-1/2” Liner cut depth / TOF: 5,400’ MD Work to be performed: x RU E-line, RIH with tractor, and cut liner at ~ 5400’ MD (~40’ outside of surface casing shoe) x RD E-line x POOH on 5” dp, laying down remaining liner from cut x RIH with cement retainer and set between ~ 5260 - 5310’ (100-50’ inside surface casing shoe) x Squeeze 45 bbls cement behind retainer, unsting and pump 5 bbls on top of retainer x POOH, LD 5 dp x RU and PT 9-5/8” casing against cement retainer to 2500 psi f/ 30 minutes, chart test x RU and run killstring x ND BOPE, NU Tree x Freeze protect well x RDMO Attachments 1. Actual Schematic 2. Proposed Schematic _____________________________________________________________________________________ Revised By: CJD 4/13/20 Current Schematic Milne Point Unit Well: MPU S-56 PTD: 220-017 API: 50-029-23669-00-00 Depth MD Depth TVD ICD/Swell Packer Detail 5,517’ 4,089’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 6,075’ 4,066’Tendeka Water Swell Packer 6,588’ 4,053’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,020’ 4,061’Tendeka Water Swell Packer 7,452’ 4,064’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,925’ 4,044’Tendeka Water Swell Packer 8,482’ 4,035’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 8,994’ 4,047’Tendeka Water Swell Packer 9,588’ 4,059’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 9,979’ 4,050’Tendeka Water Swell Packer 10,779’ 4,054’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x 34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.679” Surface 5,363’ 0.0758 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.795” 5,400’ 11,086’ 0.0149 JEWELRY DETAIL No Top MD Item ID 1 11,086’ Shoe 3.970” OPEN HOLE / CEMENT DETAIL 42" ±270 ft3 12-1/4" Stg 1 –Lead 418 sx/ Tail 418 sx Stg 2 –Lead 136 sx / Tail 270 sx 8-1/2” FISH Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 500’ TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API#: 50-029-23669-00-00 Suspended by Innovation: TBD _____________________________________________________________________________________ Revised By: CJD 4/13/20 Proposed Schematic Milne Point Unit Well: MPU S-56 PTD: 220-017 API: 50-029-23669-00-00 Depth MD Depth TVD ICD/Swell Packer Detail 5,517’ 4,089’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 6,075’ 4,066’Tendeka Water Swell Packer 6,588’ 4,053’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,020’ 4,061’Tendeka Water Swell Packer 7,452’ 4,064’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,925’ 4,044’Tendeka Water Swell Packer 8,482’ 4,035’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 8,994’ 4,047’Tendeka Water Swell Packer 9,588’ 4,059’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 9,979’ 4,050’Tendeka Water Swell Packer 10,779’ 4,054’Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x 34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.679” Surface 5,363’ 0.0758 4-1/2” Liner (FISH) 13.5 / L-80 / Hyd 625 3.795” 5,400’ 11,086’ 0.0149 Tubing Detail 3-1/2” Tubing Kill String 9.3# / L-80 / EUE 8RD 2.867” Surface ±3,000’ 0.0087 JEWELRY DETAIL No Top MD Item ID 1 ±5,260’ Cement Retainer - 2 11,086’ Shoe 3.970” OPEN HOLE / CEMENT DETAIL 42" ±270 ft3 12-1/4" Stg 1 –Lead 418 sx/ Tail 418 sx Stg 2 –Lead 136 sx / Tail 270 sx 8-1/2” FISH Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 416’ TREE & WELLHEAD Tree Cameron 3 1/8" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API#: 50-029-23669-00-00 Suspended by Innovation: TBD 1 Carlisle, Samantha J (CED) From:Schwartz, Guy L (CED) Sent:Saturday, April 11, 2020 2:52 PM To:Joseph Engel Cc:Cody Dinger Subject:Re: [EXTERNAL] RE: HAK MP S-56 (PTD: 220-017) Update 4.7.2020 Joe, YouhaveverbalapprovaltosuspendwellSͲ56asproposedbelow.Submit10Ͳ403onMondayelectronically. SentfrommyiPhone OnApr11,2020,at11:36AM,JosephEngel<jengel@hilcorp.com>wrote: Thankyou,Guy. Asperourearlierconversationwewillmovetosuspendthewell.Belowisaoutlineofthe procedure/planforward.WewillsubmittheformalsundryonMonday. SͲ56SuspensionProcedure: x Currentops:haveengagedTOFwithovershotassembly x RUEͲline,RIHwithtractor,andcutlinerat~5600’MD(~300’outsideofsurfacecasingshoe) x RDEͲline x POOHon5”dp,layingdownremaininglinerfromcut x RIHwithcementretainerandsetbetween~5260Ͳ5310’(100Ͳ50’insidesurfacecasingshoe) x Squeeze45bblscementbehindretainer,unstingandpump5bblsontopofretainer x POOH,LD5dp x RUandPT9Ͳ5/8”casingagainstcementretainerto2500psif/30minutes,charttest x RUandrunkillstring x NDBOPE,NUTree x Freezeprotectwell x RDMO Pleaseletmeknowifyouhaveanyquestions. Thankyouoryourtime. Joe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503 Office: 907.777.8395 | Cell: 805.235.6265 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Saturday,April11,20208:17AM 2 To:JosephEngel<jengel@hilcorp.com> Cc:CodyDinger<cdinger@hilcorp.com> Subject:Re:[EXTERNAL]RE:HAKMPSͲ56(PTD:220Ͳ017)Update4.7.2020 Joe, Submitasundrywithproceduretosuspend.CandoverbalonceIseesteps. GuySchwartz AOGCC SentfrommyiPhone OnApr10,2020,at10:15PM,JosephEngel<jengel@hilcorp.com>wrote: Guy– IwantedtogiveyouanupdateonSͲ56.Wewereabletocutthelinerinsidesurface casingtoclearthelinerfromit,engagethetopoffish/remaininglinerstuckinopenhole andattempttofishitfree.UnfortunatelywewereunabletofishthelinerinOHfree. TheassetteamhasmadethedecisiontomoveonfromSͲ56andcompleteitatalater date,duetothetemperature/seasonalsensitive/softroadtoKͲpad–ournextwell. Wearecurrentlygettingreadytocutthelinerat~5600’(~300’outsidesurfacecasing shoe)tohavetheabilitytoOHsidetrackthewellwhenwereturn.Wewouldlike suspendoperationsonSͲ56. DoweneedtosetaCIBPorcementplugandpressuretestagainstitbeforewerunakill string? CodyandIwillworkonaformtosubmittosuspendops(orenteroperationshutdown), withschematicandoutlineofoperationsincluded,tomorrow. Noneedtorespondtonight,butIwouldliketospeakwithyouinthemorningifwe havetomobilizeaCIBPorcement. Thankyouforyourtime. ͲJoe Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503 Office: 907.777.8395 | Cell: 805.235.6265 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Tuesday,April7,202012:39PM To:JosephEngel<jengel@hilcorp.com> Cc:CodyDinger<cdinger@hilcorp.com> Subject:[EXTERNAL]RE:HAKMPSͲ56(PTD:220Ͳ017)Update4.7.2020 3 Joe, Ihadheardthatyouwerehavingissueswiththeliner.Ifyoucanretrievetheliner beforetheswellpackersarefullysetyoumaygetoutofthisok. Keepmepostedonprogress. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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 (Guy.schwartz@alaska.gov). From:JosephEngel<jengel@hilcorp.com> Sent:Tuesday,April7,202012:19PM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:CodyDinger<cdinger@hilcorp.com> Subject:HAKMPSͲ56(PTD:220Ͳ017)Update4.7.2020 Guy– IwantedtogiveyouanupdateonSͲ56,whilerunningourlinerlatelastweektheliner hangerinadvertentlysetat~1780’MD.Itwasfoundonotherlinerhangersystemsthat werepartofthesamebatchthatitwasassembledincorrectlywhichcausedthe prematuresetasweranthroughahigherdogleg. Attemptsweremadetofishthelinerhangerfreewithnoprogress,thedecisionwas madetostopjarringtopreventdamagetothesurfacecasingfromhangerslips,andthe hangerwasmilledupovertheweekend. Currentlyweareperformingacleanoutrunoftheliner,postmillingtoclearanydebris, andpreparingforaelinecutoftheliner. OncethelinerisclearofthesurfacecasingandhopefullysomeoftheOH,wemay eitherperformacleanoutrun,sidetrackandredrillthelateralifsomeofthelinerisstill stuckintheOH,orsuspendthewell.Ataminimum,wewillremovethestucklinerfrom thesurfacecasingsection,whichwillbeournextdecisionpoint. Iwillkeepyoupostedhowoperationsgo. Pleaseletmeknowifyouhaveanyquestions. Joe 4 Joe Engel | Drilling Engineer | Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 | Anchorage | AK | 99503 Office: 907.777.8395 | Cell: 805.235.6265 THE STATE °'ALASKA 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 S-56 Hilcorp Alaska, LLC Permit to Drill Number: 220-017 Surface Location: 3221' FSL, 533' FEL, SEC. 12, T12N, RI OE, UM, AK Bottomhole Location: 189' FNL, 1073' FWL, SEC. 1, T12N, RI OE, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced service well. Per Statute AS 3 1.05.03 0(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, Wer Price air DATED this ;� day of March, 2020. AL,. -KA OIL AND GAS CONSERVATION COMMi— .ION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑� Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj 0 Single Zone ❑✓ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022224484 MPU S-56 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 14,368' TVD: 4,043' Milne Point Unit Scharder Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3221' FSL, 533' FEL, Sec 12, T12N, R10E, UM, AK ADL380109 - Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2051' FSL, 1933' FEL, Sec 12, T12N, R10E, UM, AK LONS 01-001 3/7/2020 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 189' FNL, 1073' FWL, Sec 1, T12N, R10E, UM, AK 2560 2050'to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 63.4' 15. Distance to Nearest Well Open Surface: x-565478 y- 5999884 Zone -4 GL / BF Elevation above MSL (ft): 36.9' to Same Pool: 40' TVD to MPU S-33 16. Deviated wells: Kickoff depth: 500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 1789 Surface: 1381 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) Cond 20" - X52 Weld 107' Surface Surface 107' 107' –270 ft3 Stg 1 - L - 898 ft3 / T - 458 ft3 12-1/4" 9-5/8" 40# L-80 TXP 5,578' Surface Surface 5,578' 4,063' Stg 2 - L - 1937 ft3 / T - 314 ft3 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 8,940' 5,428' 4,072' 14,368' 4,043' 1 Cementless Injection Liner ICDs Tubing 3-1/2" 9.3# L-80 EUE 8RD 5,428' Surface Surface 1 5,428 1 4,072' Tieback 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 ❑� 20. Attachments: Property Plat ❑� BOP Sketch Drilling Program Time v. Depth Plot ❑ ❑ ❑✓ Shallow Hazard Analysis ❑ Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 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 hllcor .com Authorized Title: Drillin Manager Contact Phone: 777-8395 Authorized Signature: ( Date: Commission Use Only Permit to Drill API Nu r: Permit Appro I n 2 See cover letter for other Number: — Q 50-P _ a3 6 — 00— 06 Date: (/V�j� requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbe met ane, gas hydrates, or gas contained in shales: Other: -3 c) cc "�� s � ��, P lc�s f Samples req'd: Yes ❑ No [� Mud log req'd: Yes ❑ No [� H2S measures: Yes ❑ No [-�,/ Directional svy req'd: Yes YNo❑ Spacing exception req'd: Yes ❑ No L Inclination -only svy req'd: Yes ❑ o [Er Post initial injection MIT req'd: Yes [o ❑ APPROVED BY 4 Approved by: COMMISSIONER THE COMMISSION Date: II Form 10-40 ed 5/2 1 `permit i5 valid for 2yal G-141rGA-41APL -Z-z�-z/i�� 0 AAC 25.005(8) Submn Form and Attachments in Duplicate gi � >U WO &Mao m r,ti N 0, D In O O w V M M N w U w w U V u u U w U w U w U w U w V w U w U w V m w J lD V -p M f0 w "O lD (0 w w J w J wm- J w J w J 4m- J VI 00 m �� w w J w J Vl w J VI w J J Vl w J VI w J Vf yo '^ `^ is ¢ `^ V1 o In 0 N 0 to o a N o o io Q In o 0 o In o o 0 o C o c U o 5 C U aO - o C U C C C C Z C C o c U Z C C C C C C C m w . m u t`o m u m m u w E w E w E w E w E w E tYa m u w E w E w E w E w E w E w E OE N w u m n c o m n c o m n c o w u w u w u w u w u w u m n c o w u w u w u w u w u w u w u u I=u u u a I� E w u E u !, E u E u W Z C C c I- IA "O -O -O -6 -O -O -O -O -6 -O -a -O 'O "O 'm -0 -O -0 al 7 a) 0) w w a) a) w w w D- a) (v (U O- a) CL a) a) a) a) a) -Q V V7 N VI N VI h N N N O N N N O VI O VIN to V7 to m O O O _O O _O 0 0 0 +,0 O O +, _O +, _O _O _O O _O S rn U U U U U U U U U O D U U O U O D U U U U Z Z Z _ W O O w a� a� w w w O w w a) w w w w O aJ Q U m N I, ri Q t\ u m u m u m u m Q u m u m Q u m u m u m u m u m u m u m O E F. 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S-25 S-90 S-02 S-30 1 S-15 S-12 A-250� 17L1 S -12L1 _ S. 05L1 S-11 S -23L1 S-05 S-14 S-23-4 X17 S-33 -1 � � S � N, .�> S-31 4,33A 1 � � _ ` I S S-37 S-24\�, S-56 wp02 f S-26 \,zi S-11 L 5 0 0' f r m U n i B o u n d a r y Hilcorp Alaska, LLC Milne Point Unit (MPU) S-56 Drilling Program Version 1 2/14/2020 Table of Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 RU and Preparatory Work...........................................................................................................10 10.0 NU 13-5/8" 5M Diverter Configuration.......................................................................................11 11.0 Drill 12-1/4" Hole Section.............................................................................................................13 12.0 Run 9-5/8" Surface Casing...........................................................................................................16 13.0 Cement 9-5/8" Surface Casing.....................................................................................................21 14.0 BOP NU and Test..........................................................................................................................26 15.0 Drill 8-1/2" Hole Section...............................................................................................................27 16.0 Run 4-1/2" Injection Liner (Lower Completion)........................................................................32 17.0 Run 3-1/2" Tubing (Upper Completion).....................................................................................36 18.0 Innovation Rig Diverter Schematic.............................................................................................38 19.0 Innovation Rig BOP Schematic....................................................................................................39 20.0 Wellhead Schematic......................................................................................................................40 21.0 Days Vs Depth................................................................................................................................41 22.0 Formation Tops & Information...................................................................................................42 23.0 Anticipated Drilling Hazards.......................................................................................................43 24.0 Innovation Rig Layout..................................................................................................................46 25.0 FIT Procedure................................................................................................................................47 26.0 Innovation Rig Choke Manifold Schematic................................................................................48 27.0 Casing Design.................................................................................................................................49 28.0 8-1/2" Hole Section MASP............................................................................................................50 29.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................51 30.0 Surface Plat (As Built) (NAD 27).................................................................................................52 Hilcorp Energy Company 1.0 Well Summary Milne Point Unit S-56 SB Injector Drilling Procedure Well MPU 5-57 Pad Milne Point "S" Pad Planned Completion Type 3-1/2" Injection Tubing Target Reservoir(s) Schrader Bluff NE Sand Directional Plan WP03 Planned Well TD, MD / TVD 14,368' MD / 4,043' TVD PBTD, MD / TVD 14,358' MD / 4,043' TVD Surface Location (Governmental) 3221' FSL, 533' FEL, Sec 12, T12N, R10E, UM, AK Surface Location (NAD 27) X= 565,478 Y= 5,999,884 Top of Productive Horizon (Governmental) 2051' FSL, 1933' FEL, Sec 12, T12N, RI OE, UM, AK TPH Location (NAD 27) X= 564,088 Y= 5,998,703 BHL (Governmental) 189' FNL, 1073' FWL, Sec 1, T12N, R10E, UM, AK BHL (NAD 27) X= 561,742 Y=6,007,003 AFE Number 2010573 AFE Drilling Das 17 days AFE Completion Das 3 days AFE Drilling Amount $3,741,630 AFE Completion Amount $1,626,542 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1,381 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1,789 psig Work String 5", 19.5#, S-135, DS -50 & NC 50 KB Elevation above MSL: 26.5 ft + 36.9 ft = 63.4 ft GL Elevation above MSL: 36.9 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 Milne Point Unit 5-56 SB Injector Hilco+rn�+ Drilling Procedure Energy Company 2.0 Management of Change Information 14 Hilcorp Alaska, LLC Hilcorp E..W t' T Changes to Approved Permit to Drill Date: 2194t2020 1 Subject: Changes to Approved Permit to Drill for MPU S-56 File f#: MPU 5-56 Drilling and Completion Program Any modifications to MPU 3-56 Drilling & Completion Program will be documented and approved below Changes to an approved APD YOH be approved in advance to the AOGCC. Approval: Drilling Manager Prepared: Drilling Engineer Page 3 ure Date Date Hilcorp Energy Company 3.0 Tubular Program: Milne Point Unit S-56 SB Injector Drilling Procedure Hole Section OD (in) ID (in) Drift in Conn OD in(#/ft) Wt Grade Conn Burst (psi) Collapse (psi)(k-lbs) Tension Cond 20" 19.250" - - - X-52 Weld Min Max) (k -lbs 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 8-1/2" 4-1/2" 3.960" 3.795" 4.714" 13.5 L-80 H625 9,020 8,540 279 Tubing 3-1/2" 2.992" 2.897" 4.500" 9.3 L-80 Txr-SR 9,289 7,399 163 4.0 Drill Pipe Information: Hole OD ID (in) TJ ID TJ OD Wt Grade Conn Mfu M/U Tension Section in in in(#/ft) Min Max) (k -lbs Surface & 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560klb Production 5" 4.276" 3.25" 6.625" 19.5 S-135 NC50 31,032 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 5.0 Internal Reporting Requirements Milne Point Unit S-56 SB Injector Drilling Procedure 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 pmazzolinighilcorp.com, mmyersghilcoM jengel@hilcorp.com and cding_er@hilcoM.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam 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 -Run" Casing tally to mmyersghilcorp,com jengel@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers(cr�,hilcorp.com jengel@hilcorp.com and cdinger@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 Lngel@hilcorp.com Completion Engineer Ian Toomey 907.777.8434 907.903.3987 itoomey@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kflemin,@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Milne Point Unit S-56 SB Injector x Hilco Drilling Procedure E it Company 6.0 Planned Wellbore Schematic Qt -- K5 Eek: Ea.41GL Eew.:-Xig TD=14,31 '[KOJTD=4)D8'{TVt1 PBTD= 9EB' (Nq JP6TI)=4,DVIT.DJ Page 6 Milne Pain` Uni; Well: MPU S-56 Proposed Schematic PTD: TBD API: TBD -------- - - - - ----------------------, TREE &WELLHEAD Tree I Cameron -s 1,/8" 5Mwl4-lf16"SM Canwron Wirtq Wellhead I Cameron f1"SKx4tk a kbLttomw/12I 2-1/16"SKaut3 --------------------------------- OPEN HOLE % CEMENT DETAIL 42" ±270 ft3 Sig l -Lead 855 ft3 /Tai! ASS ft3 12-1J4" Sig 2 -Lead 1937 ft3 j Tail 314 ft3 &1/2" -CVWCZV= Injecian Liner in 8-112" hale .---------------------------------------------------------------------------------------------- Top MD CASING DETAIL Upper Completion 1 TLD 3-1/2" XN Nipple, 2.913' P•ackin, Bcrq. 2.75' NrrGo, w1R11C 2.750" 2 TRO 3-1/d" GauM Mandrel SGM-XPOG wl V Wire 2.992` 3 TDO 8.25' Ne Gu Lacater Sub 12.71 off No- al 5.170'" Size Type Grade/ Conn Drift ID I Top 6tm BPP 20"x34" Canductar IImulatedl 215.5 j &52i voe1d N/A I Surface 1 114' WA 9-519, Surf" 40/L-80/TXP 1 8.679 Surface 1 5,578' 0A758 4-1)2" Liner 13.51L-80/ 625 1 3-795" 1 5,428 .4.368` DA149 TUBING DETAIL 3-15.. 1 Tubing 9.3 1 L-80 I CUE PRD 1 2.867' 1 Surf I 5428 DA670 f� fA t WELL INCLINATION DETAIL KOP [ SW 11deAn a@XN=TBD' 11deAngle@Liner Top=TLD' Max Itak!Angie =TDL7' ---------------------------------------------------------------------------------------T-- JEWELRY DETAIL No Top MD item ID Upper Completion 1 TLD 3-1/2" XN Nipple, 2.913' P•ackin, Bcrq. 2.75' NrrGo, w1R11C 2.750" 2 TRO 3-1/d" GauM Mandrel SGM-XPOG wl V Wire 2.992` 3 TDO 8.25' Ne Gu Lacater Sub 12.71 off No- al 5.170'" 4 TDD 7.375" Tieback above the SLZXP Liner Top Packer 6.170" f ower completion S 15,42D' 7' x 95,+8" YZX:P Liner Top Rucker with 7.38' Seal 2.3re 6 14,368' Shoe Depth Depth ICE)/Swell Packer Detail MD TVD Too ------------------------------------------ 6 ENERAL WELL I NFO APIA=TDO Com feted lx Innovation: TDD 7.0 Drilling / Completion Summary Milne Point Unit S-56 SB Injector Drilling Procedure MPU S-56 is a grassroots injector planned to be drilled in the Schrader Bluff NE sand. S-56 is part of a two well program targeting the Schrader Bluff NE sand on S -Pad.—' J The directional plan is a catenary well path build, 12-1/4" hole with 9-5/8" surface casing set into the top of the Schrader Bluff NE sand. An 8-1/2" lateral section will then be drilled. A 4-1/2" ICD injection liner will 1be run in the open hole section. �f The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately March 7, 2020, pending rig schedule. Surface casing will be run to 5,578' MD / 4,063 TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. MIRU Innovation to well site 2. NU & Test 13-5/8" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing. 4. ND diverter, NU & test 13-5/8" x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 4-1/2" injection liner. 6. Run 4-1/2" tubing. 7. ND BOP, NU Tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) ./ Page 7 Milne Point Unit S-56 SB Injector Hilco Drilling Procedure E—Ky nom 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 5-56. Ensure to provide AOGCC 24 hrs 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. • Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivard@hilcorp.com for submission to AOGCC. • Hilcorp Alaska proposes to demonstrate isolation of the injected fluid as required under 20 AAC 25.412 (d) through cement job operational reports of a complete two stage cement job on the 9-5/8" surface casing. Planned surface cement volumes and cement returns to surface seen during both stages will indicate placement of cement in the entire surface casing annulus. A successful FIT after surface casing drill out will demonstrate isolation of injection fluid. AOGCC Regulation Variance Requests: Hilcorp Alaska LLC does not request any variances at this time. Page 8 Summary of BOP Equipment and Test Requirements Milne Point Unit 5-56 SB Injector Drilling Procedure Hole Section Equipment Test Pressure(psi) 12 1/4" • 13-5/8" 5M CTI Annular BOP w/ 16" diverter line Function Test Only • 13-5/8" x 5M Control Technology Inc Annular BOP Initial Test: 250/3,000 • 13-5/8" x 5M Control Technology Inc Double Gate o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" • 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250/3,000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3,000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • 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.reggkalaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy. schwartz(2alaska.goy Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria. loepp(a,alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse(co>>,alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectorsgalaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Milne Point Unit S-56 SB Injector HilcE-Wom Drilling Procedure it no 9.0 RU and Preparatory Work 9.1 S-56 will utilize a newly set 20" conductor on S -Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4" nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and RU. 9.6 Rig mat footprint of the rig. 9.7 MIRU Innovation Rig. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<80°F). 9.10 Set test plug in wellhead prior to NU diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Ensure 5" liners in mud pumps. • White Star Quattro 1300 HP mud pumps are rated at 4,097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 10 Hilcorp E—gy Company 10.0 NU 13-5/8" 5M Diverter Configuration Milne Point Unit S-56 SB Injector Drilling Procedure 10.1 NU 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic attached to program). • NU 20" x 13-5/8" DSA • NU 13 5/8", 5M diverter "T". • NU Knife gate & 16" diverter line. • Ensure diverter RU 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. • Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • 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 11 Milne Point Unit S-56 SB Injector Hilcorp Drilling Procedure E—u Com 10.5 Rig & Diverter Orientation: *Orientation may differ on location Page 12 I 4a I I +S— 56 �I 37-2Qi I ■ 20+ I ?S' Radius Cigar of Ignition Source% — Diverter Line MPU S Pad *Drawing Not To Scale 11.0 Drill 12-1/4" Hole Section 11.1 PU 12-1/4" directional drilling assembly: Milne Point Unit S-56 SB Injector Drilling Procedure • Ensure BHA components have been inspected previously. • Drift and caliper all components before MU. 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 DS50 & NC50. • Run a solid float in the surface hole section. 11.2 5" Drill string, HWDP, and Jars will come from Weatherford. 11.3 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 12-1/4" hole section to section TD, in the Schrader NE 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. • 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 j ets hooked up and be ready to j et 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. J • Gas hydrates may be present on S -Pad. S -15i encountered hydrates in 2002, no other well have seen hydrates. If seen, they are typically around 2,100-2,400' TVD (lust below permafrost). Be prepared for hydrates: Page 13 / Milne Point Unit S-56 SB Injector Drilling Procedure • 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 • 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 • A/C: There are not wells with a clearance factor < 1.0 11.5 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. Page 14 Depth Interval MW (ppg) Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (For Hydrates if need based on offset wells) MW can be cut once —500' below hydrate zone • 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) BARACARBsBAROFIBRE/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. • 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). Milne Point Unit S-56 SB Injector Drilling Procedure System Type: 8.8 — 9.8 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Section - Densi Viscosity Plastic Viscosity Yield Point API FL pH Tem Surface J 1 8.8 — 9,0 1 75-175 1 20-40 25-45 <10 8.5-9.0 as required for 8.8 — 9.2 ppg f'::�kW'B'L G System Formulation: Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 - 20 ppb caustic soda 0.1 ppb (8.5 — 9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8 — 9.2 ppg PAC -L /DEXTRID LT if required for <10 FL ALDACIDE G 0.1 ppb 11.6 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. • This is to prevent washing out directional work to land the well 11.7 RIH to bottom, proceed to BROOH to HWDP • Pump at full drill rate (400-600 GPM), and maximize rotation. • Pull slowly, 5 — 10 FPM. • 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. 11.8 TOOH and LD BHA 11.9 No open hole logging program planned. Page 15 J Z Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 RU and pull wearbushing. Milne Point Unit S-56 SB Injector Drilling Procedure 12.2 RU Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and MU to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • RU of CRT if hole conditions require. • RU a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.750" on the location prior to running. • Be sure to count the total 9 of joints on the location before running. • Keep hole covered while RU casing tools. • Record OD's, ID's, lengths and SN's of all components with vendor & model info. 12.3 PU shoe joint, visually verify no debris inside joint. 12.4 Continue MU & thread lockina 120' shoe track assemblv consisting of. 9-5/8" Float Shoe 1 joint — 9-5/8" TXP, 2 Centralizers 10' from each end with stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint with stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle `Top Hat' 1 joint — 9-5/8" TXP, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle • Ensure proper operation of float equipment while picking up. • Ensure to record SN's of all float equipment and stage tool components. Page 16 Hilcorp E—w C—pY 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 2 5 U- Battle Adapter (it used) IQ Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole TD "Reference Casing Sales Manual Section 3 Page 17 "A Hikorp ES41 Running Order Part No. O4verall Length B Wn. ID After Drillout C OD Max. Teal GD D V ©penimg Seat ID E OD Closing SeatID Plug Set Hikorp ES41 Running Order Part No. ESO Cementer SO No_ Closing Plug OD Baffle Adapter Opening Plug V OD_ OD Shut-off Plug OD Bypass Plug (if used) OD Milne Point Unit S-56 SB Injector Drilling Procedure Hikorp ES41 Running Order ESO Cementer Shut OH Plug Baffle Adapter V By -Pass Plug By Pass Baffle Float Collar F%oatshoe Hilcorp Energy Company Milne Point Unit S-56 SB Injector 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: Verify depth of lowest Ugnu water sand for isolation with Geologist Depth Interval Centralization Shoe — 1000' Above Shoe 1/joints 1000' above Shoe — 2000' above Shoe (Top of U ng_u) 1/ 2 joints 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 POOH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at least 100' TVD below the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used). • Install centralizers over couplings on 5 joints below and 10 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. 9-5/899 9 40#9 L-80, TXP MU Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Page 18 Milne Point Unit S-56 SB Injector Hilcorp Drilling Procedure E -My Com TXPCP,,'BTC .-- W08i2018 collapse 3090 psi GEOMETRY Connectkn OD 10.625 in. Coupling Lengih 10.825 in. Connection ID 8.823 in Wake-up _css 4.831 in. Threaas per ir, 5 Connection 00 Option REGULAR PERFORMANCE Tension =_ifriency 100,: IointYiatii Strs_.ngh 916-000 x1000 Internal Pressure Capacirj III 5750.000 psi Ihs Ccnlpression Efficiency 100 GDmpreseion Strength 916.000 x1000 Max. Alioivabk- Sending 311'100 ft Itis Extemal Pness, re Capaairy 3090.088 pe, I MAKE-UP TORQUES I Minimum 18860 ft -;-'s Optimum 20958 Nbs Maximum 23060 ft-Ihs OPERATION LIMIT TORQUES Operating Torque 35600 Vets Yield Torque 43400 hobs N otes This connection is fulls interchangeable with: TXP& BTC - 9.625 in. - 36 J 43.5147 153.5 ! 58.4 IbVft [1] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C3 I 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 Outside Diameter 9.625 in. Min. Wall 87-5% Thickness �"� Grade L817 Type 1 Wall Thickness 0.395 in- Connection OD REGULAR Option COUPLING PIPE BODY Body: Red 1st Sand: Red Gradt L80 Type 1" Drift API Standard ist Band: Broom 2rc Sand: 2nd Sand: - Brown Type Casing 3rd Bard: - 3rc Bard: - 41h Banc: - :!IVA 11 GEOMETRY Nominal 00 9.625 in. NUminal Weight 40 lbs,ft Drift 8.679 in. Nominal ID 8.835 in WuIThickness 0.395 Plain End ?height 38.97ibs"ft OD Tolerance AN PERFORMANCE Body Y*U Strength 916 x1COD Its trtema l Y ei3 5758 psi SMYS 86008 psi collapse 3090 psi GEOMETRY Connectkn OD 10.625 in. Coupling Lengih 10.825 in. Connection ID 8.823 in Wake-up _css 4.831 in. Threaas per ir, 5 Connection 00 Option REGULAR PERFORMANCE Tension =_ifriency 100,: IointYiatii Strs_.ngh 916-000 x1000 Internal Pressure Capacirj III 5750.000 psi Ihs Ccnlpression Efficiency 100 GDmpreseion Strength 916.000 x1000 Max. Alioivabk- Sending 311'100 ft Itis Extemal Pness, re Capaairy 3090.088 pe, I MAKE-UP TORQUES I Minimum 18860 ft -;-'s Optimum 20958 Nbs Maximum 23060 ft-Ihs OPERATION LIMIT TORQUES Operating Torque 35600 Vets Yield Torque 43400 hobs N otes This connection is fulls interchangeable with: TXP& BTC - 9.625 in. - 36 J 43.5147 153.5 ! 58.4 IbVft [1] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C3 I 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 Milne Point Unit S-56 SB Injector 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 with 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 PU landing joint and MU to casing string. Position the casing shoe ±10' from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold MU water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 20 Milne Point Unit S-56 SB Injector Hilcorp Drilling Procedure Energy Cmnp 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • 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/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. E7 S 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 1St stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. == Estimated 1St Stage Total Cement Volume •t /-- Page 21 -?6's S.. K 9-1-r - Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" t} (4,598'- 2,500') x .0558 bpf x 1.3 = 152.2 854.5 J Casing l a 7 Total Lead 152.2 854.5 12-1/4" OH x 9-5/8" (5,598' - 4,598') x .0558 bpf x 1.3 = 72.5 407 — Casing rA (� ~ 9-5/8" Shoe Track 120'x .0758 bpf = 9.1 51.09 Total Tail 81.6 458 Page 21 -?6's S.. K 9-1-r - Milne Point Unit S-56 SB Injector Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. 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: 5,478' x.0758 bpf = 415.3 bbls 80 bbls of tuned spacer to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 Lead Slurry Tail Slurry Density 12.0 Ib/gal 15.8 Ib/gal Yield 2.35 ft3/sk 1.16 ft3/sk Mixed Water 13.92 gal/sk 4.98 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: 5,478' x.0758 bpf = 415.3 bbls 80 bbls of tuned spacer to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 Hilcorp s -W car Milne Point Unit S-56 SB Injector Drilling Procedure 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3,300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 23 Hilcorp E-gy co.wny Second Stage Surface Cement Job: Milne Point Unit S-56 SB Injector Drilling Procedure 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. (If ESIPC is used and packer element inflated, CBU xl minimum before pumping second stage). Hold pre job safety meeting. 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"a stage. 13.23 Cement volume based on annular volume +open hole exc 00%for lead and 100% for tail . Job will consist of lead & tail, TOC brought to surface. Howe cemen wi con inue o e 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) 20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 J 12-1/4" OH x 9-5/8" Casing (2,000'- 110') x .0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 — 12-1/4" OH x 9-5/8" Casing (2,500'- 2,000') x .0558 bpf x 2 = 55.8 314 ~ Total Tail 55.8 314 Cement Slurry Design (2nd stage cement job): Page 24 Lead Slurry Tail Slurry System Permafrost L Density 10.7 Ib/gal 15.8 Ib/gal Yield 4.41 ft3/sk 1.17 ft3/sk Mixed Water 22.02 gal/sk 5.08 gal/sk Page 24 Milne Point Unit S-56 SB Injector Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2,500' 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 1,000 — 1,500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: • 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 • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • 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 jengelghilcorp. com and cdin eerrghilcorp. com This will be included with the EOW documentation that goes to the AOGCC. Page 25 Milne Point Unit S-56 SB Injector Drilling Procedure 14.0 BOP NU and Test 14.1 ND the diverter T, 16" knife gate, 16" diverter line & NU 11" x 13-5/8" 5M casing spool. 14.2 NU 13-5/8" x 5M CTI BOP as follows: • 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 2-7/8r"LX5--10 11XBRs in top cavity, blind ram in bottom cavity. • Single ram should be dressed with 2-7/8" x 54/2" VBRs or 5" Solid Body Rams 156 • NU 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 & HCR valve on choke side of mud cross. (manual valve closest to mud cross) 14.3 Run 5" BOP test plug (if not installed previously). • Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. • Confirm test pressures 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 14.4 RD BOP test equipment 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.7 Set wearbushing in wellhead. 14.8 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.9 Ensure 5" liners in mud pumps. Page 26 Hilcorp E -W C—ps.y 15.0 Drill 8-1/2" Hole Section 15.1 MU 8-1/2" Cleanout BHA (Milltooth Bit & 1.22° PDM) Milne Point Unit S-56 SB Injector Drilling Procedure 15.2 TIH with 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on morning report. Drill out stage tool or ESIPC. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 RU and test casing to 2,500 psi for 30 minutes charted. Ensure to record volume / pressure and plot on FIT graph. AOGCC reg is 50% of burst = 6870 / 2 = —3500 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20' of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12 ppg EMW� Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 15.8 POOH & LD Cleanout BHA 15.9 PU 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before MU. 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 RU 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#, 5-135, 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. Page 27 Milne Point Unit S-56 SB Injector 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) for sufficient hole cleaning • 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 Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 — 9.5 ppg Baradrill-N drilling fluid Properties: Section Density Plastic Viscosity Yield Point Total Solids MBT HPHT Production 8.9-9.5 15-25 20-25 <10% <7 <11.0 J System Formulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N -VIS 1.0 — 1.5 ppb DEXTRID LT 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 1 0.015 ppb 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid Page 28 or4V = 8. N-6' Hilcorp E -W co.p., Milne Point Unit S-56 SB Injector Drilling Procedure 15.13 Begin drilling 8-1/2" 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 PU off bottom and restart on bottom staging technique. If stick slip continues, consider adding 0.5% lubes. 15.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 GPM, target min. AV's 200 FPM, 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. • 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 NB Concretions: 4-6% of lateral • Anticipate similar concentrations in NE • A/C, wells with < 1.0 clearance factor: • S -17L1: Lateral in the OA Sand, no geological risk • S-20: Dual string injector in OA and OB Sand, no geological risk • S-24: Lateral in NB Sand, no geological risk • S-28: Lateral in NB Sand, no geological risk • S-29: Lateral in OB & OA sands, no geological risk 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 approximately 30 minutes. • Time drill at 4 to 6 FPH with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. Page 29 Hilcorp Energy Company Milne Point Unit S-56 SB Injector Drilling Procedure 15.16 At TD, CBU at least 4 times at 200 FPM AV (385+ GPM) and rotation (120+ RPM). Pump tandem sweeps if needed • 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 9.0 ppg minimum 15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Lineup to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 15.18 Displace 1.5 OH + Liner volume with viscosified brine. • Proposed brine blend (same as used on M-16, aiming for an 8 on the 6 rpm reading) - KCl: 7.1bbp for 2% NaCl: 60.9 ppg for 9.4 ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5 pH Busan 1060: 0.42ppb Flo -Vis Plus: 1.25 ppb Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOK Record SO, PU weights and rotating torque to compare to pre -brine values in report. 15.19 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (less if losses are seen, 350 GPM). • Rotate at maximum rpm that can be sustained. • Pulling speed 5 — 10 min/stand (slip to slip time, not including connections), adjust as dictated by hole conditions • If backreaming operations are commenced, continue backreaming to the shoe 15.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH. 15.21 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. Page 30 Milne Point Unit S-56 SB Injector Hilco Drilling Procedure t.e.W Co.� 15.22 Monitor well for flow / pressure build up with MPD. Increase fluid 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 15.23 POOH and LD BHA. 15.24 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 31 Hilcorp Energy Company 16.0 Run 4-1/2" Injection Liner (Lower Completion) Milne Point Unit S-56 SB Injector Drilling Procedure 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2" liner with ICD and swell packers, the following well control response procedure will be followed: With ICD across the BOP: PU & MU the 5" safety joint (with 4-1/2" crossover installed on i/ bottom, TIW valve in open position on top, 4-1/2" handling joint above TIW). This joint shall be fully MU and available prior to running the first joint of 4-1/2" liner. •Wit h 4-1/2" solid joint across BOP: Slack off and position the 4-1/2" solid joint to MU the TIW valve. Shut in ram or annular on 4-1/2" solid joint. Close TIW valve. 16.2. Confirm VBR have been tested on 3-1/2" and 5" test joints to 250/3,000 psi. 16.3. RU 4-1/2" liner running equipment. • Ensure 4-1/2" Hydril 625 x DS -50 crossover is on rig floor and /U to FOSV. • Ensure the liner 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 RU casing tools. • Record OD's, ID's, lengths and SN's of all components with vendor & model info. 16.4. Run 4-1/2" injection liner. • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only with paint brush. Wipe off excess. Thread compound can plug the ICDs. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Use lift nubbins and stabbing guides for the liner run. • Fill 4-1/2" liner with PST passed mud (to keep from plugging ICDs with solids) • Install ICDs and swell packers as per the Running Order (Estimate 8 evenly spaced, Operations Engineer to provide confirmation of set depths). • Do not place tongs or slips on swell packer elements or ICDs. • ICD and swell packer placement ±40' • The ICD connection is 4-1/2", 13.5#, L-80, Hydril 625. • Remove protective packaging on swell packers just prior to picking up • If liner length exceeds surface casing length, ensure centralizers are placed 1/joint for each joint outside of the surface shoe. This is to mitigate difference sticking risk while running inner string. • Obtain PU and SO weights of the liner before entering open hole. Record rotating torque at 10 and 20 RPM 4-1/299, 13.5#9 L-80, Hydril 625 MU Torques Casing OD Minimum Optimum Maximum Operating Tor ue Yield Torque 4-1/2" 8,000 ft -lbs 9,600 ft -lbs 12,800 ft -lbs 15,000 ft -lbs Page 32 s Hilcorp E W Company For the latest performance data, always visit our website: www.tenaris.com Wedge 625@ Outside Diameter 4.500 in. Wall Thickness 0-290m- Grade 290us.Grade LBO Type 1' E" _ GEOMETRY Min. wall 87.5% Thickness Connection OD REGULAR Option Drift AN Standard Type Casing Milne Point Unit S-56 SB Injector Drilling Procedure r,xn.d — 1210412017 t7 Grade LBO 4.500 ;n. Type 1 Nominal ID COUPLING PIPE BODY Body Red 1st Band: Red 1st Band: Brown 2nd Band: 2nd Band: - Brom Sac Band: - 3rd Band: - Internal geld 9020 ps: .SMYE 80000 psi 4th Band: - Nominal OD 4.500 ;n. Nominal Weight 13.50 ts1t Drift 3.795m. Nominal ID 3.920 in. Wal Thickness 0.290 in. Plain End Weight 13.05 bs�t CO Trance API Conrecton OD Option PERFORMANCE Body Yw9d Strength 307 AODO lbs Internal geld 9020 ps: .SMYE 80000 psi Collapse 8540 psi Ionn t.:,, OC 4.714 n. Connectkn ID 3.849 in. Make-up Loss 4.830 at. Threads per in 3.59 Conrecton OD Option REGULAR PERFORMANCE Tension Efficiency 91.0% Joint Yield Strenglh 279.370 x1000 Internal Pressure Capacity 9020.000 psi Its Compression Eficrexy 94.5 % Compression strength 290.115 x1O:C Max. A1lorrable Bending 737 *7100 3 Itis External Pressure Capacity 8540MG psi MAKE-UP TORQUES Minimum 8000 ft4bs Optimum 9600 114b Maximum 12800 ft4bs OPERATION LIMIT TORQUES Cperaeryg Torque 12800 h-Ibs Yield Torque 15000 dNbs Notes Fat further information on concepts indicated in this datasheet, download the Datasheet Manual from w w.tenaris_com 16.6. Ensure that the liner top packer is set —150' MD above the 9-5/8" shoe. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Ensure hanger/packer will not be set in a 9-5/8" connection. 16.7. Before picking up Baker SLZXP liner hanger/packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. Page 33 Hilcorp Energy Company Milne Point Unit S-56 SB Injector Drilling Procedure 16.8. MU Baker SLZXP liner hanger/packer to 4-1/2" liner. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 minutes for mixture to set up. 16.9. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH with liner on DP no faster than 30 FPM —this is to prevent buckling the liner and drill string. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. 16.11. The liner and inner string will prevent the DP from auto filling. Fill DP every 5 stands, more frequently if SOW trend indicates. 16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.13. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.14. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.15. Rig up to pump down the work string with the rig pumps. 16.16. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.17. Drop setting ball down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to shift the wellbore isolation valve closed. 16.18. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the ZXP to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,100 psi to neutralize and release running tools. 16.19. Bleed DP pressure to 0 psi, Pick up to expose rotating dog sub and set down 50K without pulling sleeve packoff. Contingency (if suspected not released from running tool) - Pick back up without pulling sleeve packoff, begin rotating at 10-20 RPM and set down 50K again. 16.20. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted. i 16.21. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. Page 34 Milne Point Unit S-56 SB Injector Drilling Procedure 16.22. POOH laying down DP then rack back enough 5" DP for the liner top cleanout run. LD and inspect the liner running tools. Once running tools are LD, swap to the Completion AFE. 16.23. Make up 3-1/2" wash tool and RIH on 5" DP to the liner top. 16.24. Flush liner top at max rate while displacing out well to clean brine. 16.25. POOH LD remaining 5" DP. Page 35 Hilcorp Enemy Company 17.0 Run 3-1/2" Tubing (Upper Completion) Milne Point Unit S-56 SB Injector Drilling Procedure 17.1 Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivard(cr�,hilcorp.com for submission to AOGCC. 17.2 MU injection assembly and RIH to setting depth. TIH no faster than 90 FPM. • Ensure wear bushing is pulled. • Ensure 3-1/2" EUE 8rd x NC -50 crossover is on rig floor and MU to FOSV. • Ensure all tubing has been drifted in the pipe shed prior to running. • Be sure to count the total # of joints in the pipe shed before running. • Keep hole covered while RU casing tools. • Record OD's, ID's, lengths and SN's of all components with vendor & model info. • Monitor displacement from wellbore while RIH. k 3-1/2" Upper Completion Running Order: X'' • 7.30" Baker Ported Bullet Nose seal (stung into the tieback receptacle, crossover to 3-1/2", 9.3#, EUE 8rd) • 3 joints (minimum, more as needed), 3-1/2", 9.3#, EUE 8rd tubing • 3-1/2" "XN" nipple at TBD (less than 70° hole angle) • 1 joints, 3-1/2", 9.3#, EUE 8rd tubing • 3-1/2" Baker gauge mandrel o Cross collar clamps: Every joint for first 10 joints, every other joint beyond this to surface • XX Joints, 3-1/2", 9.3#, EUE 8rd tubing • Space out pup(s), 3-1/2", 9.3#, EUE 8rd tubing • 1 joint, 3-1/2", 9.3#, EUE 8rd tubing • Tubing hanger with 3-1/2" EUE 8rd pin down 17.3 Locate and no-go out the seal assembly. Close annular and test to 500 psi to confirm seals engaged. 17.4 Bleed pressure and open annular. Space out the completion (::L2' above No -Go). Place all space out pups below the first full joint of the completion. Page 36 Milne Point Unit S-56 SB Injector Drilling Procedure 17.5 MU the tubing hanger and landing joint. 17.6 RIH. Close annular and test to 500 psi to confirm seals are engaged. Bleed pressure down to 250 psi. PU until ports in seal assembly exposed. 17.7 Reverse circulate the well with corrosion inhibited brine. 17.8 Freeze protect the IA to 2,000' TVD (base on actual well deviation) with diesel. 17.9 Land hanger and RILDS. 17.10 PT the IA to 2,500 psi for 30 minutes charted. i. Note this test must be witnessed by the AOGCC representative. 17.11 Set BPV, ensure new body seals are installed each time. 17.12 ND BOPE and install the plug off tool into the BPV. 17.13 NU the tubing head adapter and NU the tree. 17.14 PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 17.15 Pull the plug off tool from the BPV. 17.16 Bullhead diesel down the tubing to 2,000' TVD (base on actual well deviation). 17.17 Install all tree gauges. Secure the tree and cellar. Release the rig. 17.18 RDMO the Innovation Rig. 17.19 Turn the well over to operations via handover form. Page 37 Hilcorp Energy Company 18.0 Innovation Rig Diverter Schematic 3-118' Kill Line 13-5.8.5M Technology Sinc 13.5!'8 Page 3 8 Milne Point Unit S-56 SB Injector Drilling Procedure ;onttol Technology 3-51' 5h1 Control echnology Double Ram 118' Choke Line —16' Diverler Line ON Hilcorp E—gy C—pa.y 19.0 3-1/8" Kill Innovation Rig BOP Schematic 9-5/8" DBL D Seal Casing Hanger S-22 13-5/8" NOM 9-5/8" BTC Btm x 10.5"-4 SA Pin Top W/ Primary Seal Page 39 Milne Point Unit S-56 SB Injector Drilling Procedure 13-518" 5M Control Technology Annular BOP 13-518" 5M Control Technology Double Ram ~�-3-1/8" Choke Line ------13-518"5M Control Technology Single Ram 13-5/8"x 5M 11"x5M 2-1/16" x 5M 13-518" x 5M \,--2-1/16" x 5M 9-5/8" Casing 20.0 Wellhead Schematic Milne Point Unit S-56 SB Injector Drilling Procedure CAMERON 1 V 5K MBS A Schlumberger Company 4-1/16" 51t 11" 5K -dJ16" 51: jLLJJ 37.34" 21.25" ay li I 9-5IS" Control Linen` 24.37" Note: Di�nen--icmai anformafirn re'7ected on this drxwinr am estiawnted measurement: only. Page 40 Hilcorp Energy C.mpmy 21.0 Days Vs Depth Ia e 0 6000 8000 0 v 10000 v 2 12000 MPU S-56 SB Ne Injector Days vs Depth Milne Point Unit S-56 SB Injector Drilling Procedure ector 18000 0 5 10 15 20 25 Days Page 41 H Hilcolp Energy C..p-y 22.0 Formation Tops & Information Milne Point Unit S-56 SB Injector Drilling Procedure MPU S-56 Formations (wp03) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (Ppg) Base Permafrost 2027 1809 1872 823.68 8.46 LA3 4025 3476 3539 1557.16 8.46 Ugnu MB 4358 3712 3775 1661 8.46 Schrader Bluff NA 4826 3940 4003 1761.32 8.46 Schrader Bluff NE 5105 4005 4068 1789.92 8.46 GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL TVD FM LITH DESCRIPTION All C-1. roicranc Gobi Unconsolidated coarse to medium sand and small gravel with minor sifttone- 1,000,• Heavy gravel conglomerate to 1400'. Wood fragments throughout permafrost zone. Abundant pyrite at 150D ft. tY Base permafrost -44611 RUNNING GRAVELS 1700' 2,000' Be prepared for HYDRATE gas cut HYDRATES11 C -,d 2CO-110 2500' ss (E -land E-6) Saga % anirktok L (plus E-10. -11, -22 &-23i). (E-114-30, -4100 HYDRATES! -33 & 21)- E-32- GAS CUT MUD A Predominantly clay to +P- 3000' with Interbeds of sand, clays and Millstones w ith occasional shows of coal. Y 3,000 Continued inlerbeds of sand, clays and siffstones with occasional shows of coal. Clay, sillstone and sand interbeds between 3000 and 6000'. Logntte3400-350011- SVinter ; smare rorty ("muddit-,"}than C those in the Prudhoe Say area, nn, UCA1K,s SWABBINGISTICKY U, nee..A Ugnw Thick package -200 to 3001t In sorra areas, mostly water -filled at E -pad. allhough some zones are filled wrath hydrocarbon. The Ugnu section finterbedoed fluvial sandstone A 9 . and "14) represents the Initial progradation of the Ugnu deltaic system over the underlying CLAYYGUMBO: E -20a. -28, CID , shallow section. Schrader Bluff seon. Fluvial nature can make it difficult to determine top D y and base of Indilv4dual units. Bottom bounding surface of the entire Ugnu package Is picked -32 & -12. A at the regional unconlormny WDS )see the M -sands below)-GAS CUT MUD E-24 AT 3996 riuvial, &Plate channel sandstones prograded over the underlying shallow TVD; E-13B@3618tad. 4.000 B marine sandstones oil Ow Schrader Shift. The ht -Sands are subdivided Into three TIGH[PPACKING OFF, E -25A, A Ilthostfaltigrapftc units (W, Mb. Mc from top to bottom) that can be difficult to correlate due 4 to their ItuAd-de4taic nature. the M705 marks the lower most boundary. M -sand intervals Surface casing seat. are typically coarsening upward packages of varying thicknesses. rarxj n9from 50-80 th Ck for Schrader Bluff CAll zones are highly unconsedidato-d sandstones with porosities range in the 30-38% and 414:- pe"ne2blidies reaching upwards of 2(100-5000 md. Each 114 -sand interval acts as a ewnpletion. L4375 hydraulically separate reservoir based on current understanding. TIGHPLEDGES (COAL) cr N-SandS-' The N-sairids are composed olistacked. marine shcirefac6 sandstones that RUNNING SURFACE A upwards from thin. silty mudistones into thin, low neLgross very fine to mediurn, CASING. E-24, -33 & -25. el. grained sandstones- The NIS, KC & sands are ft* best quality reservoir rock of clean, D Y I high inel-giross fine to medium grained sandstone. "and porosity ranges from 12-3151% and 3t Z r permeabilities range horn 100-3000 md. The MC & NO -sands are the primary target, with secondary targets In the NEI -sand- the more unconsolidated sands (typically ft* NB' NC & 0 NM tend to washouL and the flner grained silly mudstones can cause slow ROP. Each N -sand acts as a hydraulically isolated separate reservoir. 4515 ga 0 -sands. The O -sands consist of stacked, lower shofelace marine sands that clean upwards from silty mudstones (intervening shates) to thin bedded, very fine to fine grained sandstones, These OA and 08 sandstoms are 25-30'thick, and the OA -sand is the primary iy M Gft—B -u target for horiZoMi wells at E -pad. Oland porosities range from 112-3151,. and permeabilhies V) in the OB -sand reach upwards, of BOG md, whereas permeabilities In the OArslind reach only — = C in 350 nul. There are underlying OB sands (015b -06f) that correlate over the region. y4r. may contain tight nodules and lenses that cause directional deflection (especially when C P: I horizontal) and slow ROP. Each O -sand Interval acts as a hydraulically Isolated r"ervott. The numerous sub -seismic 5-30 ft faults and the lateral discontinuity of the NB -sands make it 4800' essential for clear pick identification down through the Ugnu and N -sands. as well as careful D, I geosteening In horizontal wells. Page 42 N Milne Point Unit 5-56 SB Injector Hilco}+�� Drilling Procedure Energy Company 23.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hyrates have been seen on E Pad. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non - pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are a number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Well Specific A/C: • There are no wells with a clearance factor of <1.0 Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Page 43 Milne Point Unit S-56 SB Injector Drilling Procedure Treat every hole section as though it has the potential for 1-12S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 44 Hilcorp Energy Company Milne Point Unit S-56 SB Injector Drilling Procedure 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: JTreat every hole section as though it has the potential for 1-12S. No 1-12S 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 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Abnormal pressure has been seen on E -Pad. Utilize MPD to mitigate any abnormal pressure seen. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. • A/C, wells with < 1.0 clearance factor: • S -17L1: Lateral in the OA Sand, no geological risk • S-20: Dual string injector in OA and OB Sand, no geological risk • S-24: Lateral in NB Sand, no geological risk • S-28: Lateral in NB Sand, no geological risk • S-29: Lateral in OB & OA sands, no geological risk Page Hilcorp Enema Company 24.0 Innovation Rig Layout Milne Point Unit S-56 SB Injector Drilling Procedure Page 46 Milne Point Unit S-56 SB Injector Hilco Drilling Procedure Energy cow 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 47 Hilcorp Enema C..p gy 26.0 Innovation Rig Choke Manifold Schematic Milne Point Unit S-56 SB Injector Drilling Procedure Page 48 Hilcorp E-gy C -p -y 27.0 Casing Design 14 Hil=T Milne Point Unit S-56 SB Injector Drilling Procedure Calculation & Casing Design Factors Hole Size 12-1/4" Hole Size 8-1/2" Hole Size Drilling Mode MASP: 1381 MASP: DATE: 2114/2020 WELL: MPU S-56 DESIGN BY: Joe Engel n Criteria: Mud Density: 9.2 ppg Mud Density: 9.2 ppg Mud Density: attached MASP determination & calculation Production Mode MASP: 1381 psi (see attached MASP determination & calcu Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 49 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" G L - Top (MD) 0 5,297 Top (TVD) 0 4,112 Bottom (MD) 5,297 13,631 Bottom (TVD) 4,112 4,102 Length 5,297 8 3 Weight (ppf) 40 13.5 Grade L-80 L-80 Connection TV H625 Weight w/o Bouyancy Factor (lbs) 211,880 112,509 Tension at Top of Section (lbs) 211,880 112,509 Min strength Tension (1000 lbs) 916 279 - Worst Case Safety Factor (Tension) 4.32 2.48 Collapse Pressure at bottom (Psi) 2,031 2,026 Collapse Resistance w/o tension (Psi) 3,090 8,540 Worst Case Safety Factor (Collapse) 1.52 4.21 MASP (psi) 1,381 1,381 Minimum Yield (psi) 5,750 9,020 Worst case safety factor (Burst) 4.16 ✓ 6.53 Page 49 Milne Point Unit S-56 SB Injector Hilco Drilling Procedure 28.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Hill 8-1/2" Hole Section MPU S-56 Milne Point Unit MD TVD Planned Top: 5578 4063 Planned TD: 14368 4043 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OB Sand 4,063 1 1788 1 Oil 8.46 1 0.440 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date S-34 L2 8.9 4,229 4242 2003 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 9-5/8" shoe considering a full column of gas from shoe to surface: 4063 (ft) x 0.78(psi/ft)= 3169 3169(psi) - [0.1(psi/ft)*4063(ft)]= 2763 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4063 (ft) x 0.44(psi/ft)= 1788 psi / 1788(psi) - 0.1(psi/ft)*4063(ft) 1381 psi c� 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 50 Hilcorp Enema Company 29.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit S-56 SB Injector Drilling Procedure E254 ..�I�d'S^ a •. E.25'82 `♦ F 1 1 1 Via"i1.1 *�-_' _ ! _ ,` • u-09 '` �7 ADL025906' Sec 33t 1, + ` U013NO10E �a_tsas Sec. 36 I, - , il ADL025518 Sec. 35 / 1 •r H.1. S zAIS`. S-11A i• + I It %ti ZZI MPL' S_iMi BHL S -IH L Y F i H.rs • s.tsss �� I H1. ♦ Ali Sec.6 Sec: 3' H.an Seep Y �� \ Sec. t•,H-CeF-1``+ c.1cp 1t f;''7: U7IFS r+ MILNE POINT, \\ �L221 I 21 r s.z-x - 2n \ S'E__ \ S-1 r t Y 1 r ;1_ 1 r S-UPa1 e.. F �� /rte _1��\ \\� • 11 t"1� �i _ ADL380110` ADI -02 27 H -o -a 7Ps. Ff.ADL380109� ` _.__- \� r H -c -A: elHe�r,1.1 t f' r j '`�.�r.H..c6 Y S. C_c U012NO10E ss_ � +` �\` ` U012N011E Y _ ..._ a - 1+ YY $ ,ass `.tpu S -56i SHL . I H -WA t 11 L4 yl c 1 Sec? Sec_ 11 sal - _ _ - - _ _ S 7 , 1 (586? Legend Wal R%PU S-Stti TPIi Oji(( s tE.:4PS2 / ( +tai 15 1 trite. 9 MPU S-56i_SHL 01hea Bon= Hdes (BHLi X MPU S-56i_TPH�" 01he, Well Paths � �=t ��" ilms s Z 15 q ■ ■ 08 and Gas Unit Boundary- - ` -s.i x _._ ► MPU S -56i BHL as - Pad Footptin, i KUPARUK RIVER UNITADL047446 PRUDMOE BAY UNIT Sec..15 ADL025637 c c.14 Sec. 13 Sec. 18 r ' ADL025636 i583y er �t Milne Point Unit MPS -56 Well 0 1,0.00 2,000 3.000 vap Dal, 2'17:. wp03 Feet Page 51 Hilcorp Energy Compmy 30.0 Surface Plat (As Built) (NAD 27) Milne Point Unit S-56 SB Injector Drilling Procedure Page 52 I i � E_P 201 I — 25■2. r7j� 202■204 N- D 38 S` ■u i mm I ns I X30 I T72N r m 29 I 2 $ 1 5 I 5 1 ! : ie I .0 ■ I Tm PF10CT ■ 2" i I aI C- S- PAD ■ t4. I 17 I VICINITY MAP RENAMED CONDUCTOR REV1570N NOTE N.tl I S-56 ■ {6 WELL II TWS AS-OULT DRAWING IS A REISSUE OF { S-Sfi 0 2 PREVIOUS A,5-B"T DRAWN -4 KR 001"CTOR I ■ 10 S®205. RENAMED CMJVX70R IS AS FOLLOWS,, OLD GOND. NAME NEW COND. NAME 071 I S-205 S-56 3,221' FSL I 3 ------- — X= 565 478.70' E., fi 339.80' ■ _ _ _ IF tea■ I__ ( • • I j I Tmath ; . 8amhwt 200 f GRAPHIC SCALE NOTES: a s0 150 320 1 DAZE OF SUR%EY- OCTOW 14, 2010 SURVEYOR'S CERTIFICATE ( IN FEEL) 2 REfENENOE FIELD BOOK, HC1Si-U4 PO4 ?3•-24. I HEREBY CERTFY THAT I AM P ROFMY REGISTERED AND LICENSED 1 Inch a 750 H. 3. HORZONTAL DA1UM IS X"A STATE PLANE, ZONE 4, NA027, PRACTICE D SUR IN ♦ fEOCETtC Pfk9TtaN5 ARE NAD'1'1. TMHESTE A AND THIS AS -BUILT REPRESENTS A SURWY LEGEND S PAD WEAN SCA41 FACTOR 6 (L99990442 MADE BY ME OR UNDER MY DIRECT MAT ALL .�. 8. HDMZONTAL D VERTICAL CONTROL S BALD ON WP S PAD DIMENSIONS DOOTTNER DET"$ ARE AS-9UILT CONDUCTOR OPERATOR WONLMENTS S -EAST, S-WID, AND S-I{EST. COiiREOT AS OF OCTOBER 14, 2". ■ E)MSTINC CONDUCTOR 1. ETEVAPONS ARE WINE PONT MEAN SEA LEVE— LOCATED WITHIN PROTRACTED SEC. 12, T. 12 N., R. 10 E., UMIAT MERIDIAN. AK. WELL. A.S.P. PLANT GEODETIC �ODETIC GRAVEL CELLAE? SECTION N0, COORDINATES COORDINATES POSITION DMS) POS1TtON(D.DD) PAD ELEV. BOX ELEV. OFFSETS S'201 Y=5999,871.32' N-2,237.36' 70'24'36.41 6" 70.4101156' 36.8' =N'+•7� 3,213' FSL X= 565 449.79 E= 6309.93' 14978'01.437' 149.4670658' 562' FEL 5-202 Y=5,999,900,83 N=2,237.48 70'24'35,640" 70,4101778' 36.7' 36,5' 3,236'F$L, X= 565 537.D7' = 6,400.33- 149'27'58.873' 149.4683536' 474' L Y• 5,999,884.82' N- re I I Hilcorp Alaska �A�N _M `acre MPs 1a MPU S PAD AS -BUILT CONDUCTORS WELLS S-201, S-202 & S-56 'a" I or 1 M1 Jmow� owACO ur I' - 160 4,46 rot rlauna n. .n a+so. .a« Page 52 S-Sfi 2,237.13' 70'24'36.481' 70.4141353' 36.9' • 389' 3,221' FSL X= 565 478.70' E., fi 339.80' 143'28"00.588' 149.45fi8300' 533' FEL Page 52 Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S -56i MPU S -56i Plan: MPU S-56 wp03 Standard Proposal Report 10 February, 2020 HALLIBURTON Sperry Drilling Services Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S -56i Wellbore: MPUS-56i Design: MPU S-56 wp03 MALLIBUR-MIV IM sw.ry orrnmg Hilcorp Alaska, LLC Calculation Method Minimum Curvature E S t r ys em. ISCWSA Scan Method Closest Approach 3D WELL DETAILS: Plan: MPU S - SURVEY PROGRAM Error Surface: Pedal Curve Start Dir 31/100' : 500' MD, 5007VD SECTION DETAILS Date: 2019-07-05T000000 Validated: Yes Version: Warning Method Error Ratio Sec MD Inc Ali TVD +N/ -S +E/ -W Dleg TFace VSeM Target Annotation 1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.00 2304.40 2241.00 255086 SV I �O p� � ctf p° 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3°/100' : 500' MD, 500'TVD 3 800.00 9.00 185.00 798.77 -23.42 -2.05 3.00 185.00 -22.61 Start Dir4°/100': 800' MD, 798.77nVD 4 1100.00 21.00 185.00 1088.02 -100.63 -8.80 4.00 0.00 -97.13 UGNU MB - - _ .. - _ - _ _ _ _ _ _ - 5 1486.87 34.90 170.03 1429.32 -279.79 4.39 4.00 -33.63 -275.54 End Dir : 1486.87' MD, 1429.32' TVD 6 3061.17 34.90 170.03 2720.44 -1166.99 160.30 0.00 0.00 -117620 Start Dir 5-/100': 3061.17' MD, 2720.44'TV 7 5352.92 93.44 300.00 4076.90 -1282.00 -1205.64 5.00 122.72 -1029.89 End Dir : 5352.92' MD, 4076.9' TVD 8 5577.92 93.44 300,00 4063.40 -1169.70 -1400.14 0.00 0.00 -882.72 MPU S-56 WP03 CPI Start Dir 4.5°/100' : 5577.92' MD, 4063.4' D 9 5953.66 90.92 316.73 4049.02 -937.47 -169343 4.50 98.20 -599.05 End Dir* 5953.66' MD, 4049.02' TVD 10 6304.61 90.92 316.73 4043.40 -681.96 -1933.94 0.00 0.00 -302.54 MPU S-56 wp03 CP2 Start Dir 4°/100' : 6304.61' MD, 4043ATVD 11 7113.08 89.95 349.06 4037.11 28.19 -2297.40 4.00 91.54 463.68 End Dir : 7113.08' MD, 4037.11' TVD 12 14368.13 8995 349.06 4043.40 7151.35 -3674.50 0.00 0.00 7718.73 MPU S-56 wp03 Toe Total Depth : 14368.13' MD, 4043.4' TVD r ys em. ISCWSA Scan Method Closest Approach 3D WELL DETAILS: Plan: MPU S - SURVEY PROGRAM Error Surface: Pedal Curve Start Dir 31/100' : 500' MD, 5007VD Date: 2019-07-05T000000 Validated: Yes Version: Warning Method Error Ratio 600 -36.90 L4n9Butle +NI -S +EI -W Fasting LatRtutle 0.00 Ooo ..a4 565478.]0 70. 24' 36.487 N 149. 28' 058a W 5999884 82 500 End Dir : 1486.87' MD, 1429.32' TVD Depth From Depth To Survey/Plan TOOT FORMATION TOP DETAILS 26.50 900.00 MPU S-56 wp03 (MPU S -56i) 3_Gym-GC _Csg 900.00 5577.92 MPU S-56 wp03 (MPU S -5i) 3MWO-I 1200 � SV5 TVDPam TVD -th MDPath F4rmabon REFERENCE INFORMATION 14i 4.40 1411 00 1541.84 SV5 BPRF 00 _MWDFR2+MS+Sag $577.92 14366.13 MPU 856 wp03 (MPD $-561) 3_MWD+IFR2+MS+Sag Ca-artlinab (N/E) Rerarenca: Wall Plan: MPU S -56i. True N.11 1872.40 1609.00 2027.13 9PRF DETAILS 2304.40 2241.00 255086 SV I �O p� � ctf p° V.. -I (TVD) Refaraxe: MPU S-56 As -built RKB @ -.-CASING L 3539.40 34i 8.00 4025.40 LA] 377540 3712.00 4358.91 JO- MB �'�. P oJry P� °• p° Measuretl Oeptb Rererenrs: MPU S-56 As -bulk RKB @ 6340 -ft O 2400 TVD NDSS MD $IZ¢ Name 4063.40 4000.00 5577.92 9-5/8 95/8"x121/4" 400-340 ]940 00 4826.20 SB_NA - - - - - - - - :� - - - - - Calculation McN4tl: Minimum Curvature 466°4. 4gos.o0 510577 sa NE - 4043.40 3980.00 14368.13 6-5/8 6 5/8" x 6 12" p r7y��'ry 11011 n h -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 Vertical Section at 349.064 (1200 usWin) 0 Start Dir 31/100' : 500' MD, 5007VD Start Dir 44/100' : 800' MD, 798.77'TVD 600 500 End Dir : 1486.87' MD, 1429.32' TVD 7000 1200 � SV5 BPRF 00 oa 1800 �O p� � ctf p° P° L �'�. P oJry P� °• p° O- O 2400 SV1 - - - - - - - - ?500-' -�°- ��° -yy,V1 �O• --�O' - - - - - - - - - - - - - .. - - - - - - - - - :� - - - - - lb p r7y��'ry 11011 n h . 3000 h° O O .' a o6 i. mQ 2 3500 m� Hca, o ~ LA3 h mr /uc _ - 1 _ - _ - _ _ 000- _ - _ - _ _ . y _ _ - _ - - - - _ - - _- - - - - - _ __ _ - _ - - - - __ _ - _ - _ - - - 3600 UGNU MB - - _ .. - _ - _ _ _ _ _ _ - _ _ _ __ _ - _ - _. _ _._ _ - _ - _6 518" x 8 1/2" - SB NA 4200 SB NE I co Co 9 5/8" x 12 1/4" N g o o o o 0 0 o c o N o ^' w w A A MPU 5-56 wp03 O N O w m MPU S-56 wp03 CP1 MPU S-56 wp03 CP2 MPU S-56 wp03 Toe -2400 -1800 -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 Vertical Section at 349.064 (1200 usWin) 7500 MPU S-56 WP03 6 5/8" x 8 1/2" Total Depth : 14368.13' MD, 4043 4' TVD a�43 7000` MPU S-56 wp03 To 6000 5500 5000 a 3500 Z 0 0 3000 0 ZL 2500 t 5 0 2000 1500 1000 End Dir : 7113.08' MD, 4037.11' TVD 0 MPU S-56 wp03 C -500 9 5/8" x12 1/4" Start Dir 4'/100': 6304.61' MD, 4043.4'TVD _1000—End Dir : 5953.66' MD, 4049.02' TVD MPU 5-56 wp03 C ] P -1500 End Dir5352.92' MD, 4076.9' TVD HALLIBURTON Sperry Drilling Start Dir 30/100' : 500' MD, 500'IVD 0- — — - Start Dir 4o/100': 800' MD, 798.7TTVD 1250 End Dir : 1486.87' MD, 1429.32' TVD 1150 2000 Start Dir 50/100' : 3061.17' MD, 2720.441TVD 2500 2750 ']000 0 0 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 West( -)/East(+) (1000 usft/in) WELL DETAI S: Plan: MPU S -56i 36.90 +N/ -S +E/ -W 0.00 0.00 Northing Easting Latittude Longitude 5999884.82 565478.70 700 24'36.487 N 1490 28'0.588 W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan: MPU S -56i, True North Vertical (TVD) Reference: MPU S-56 As -built RKB @ 63.40usft Measured Depth Reference: MPU S-56 As-buih RKB @ 63.40usft Calculation Method: Minimum Curvature CASING DETAILS TVD TVDSS MD Size Name 4063.40 4000.00 5577.92 9-5/8 9 5/8" x 12 1/4" 4043.40 3980.00 14368.13 6-5/8 6 5/8" x 8 1/2" Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S -56i Wellbore: MPU S -56i Plan: MPU S-56 wp03 End Dir : 7113.08' MD, 4037.11' TVD 0 MPU S-56 wp03 C -500 9 5/8" x12 1/4" Start Dir 4'/100': 6304.61' MD, 4043.4'TVD _1000—End Dir : 5953.66' MD, 4049.02' TVD MPU 5-56 wp03 C ] P -1500 End Dir5352.92' MD, 4076.9' TVD HALLIBURTON Sperry Drilling Start Dir 30/100' : 500' MD, 500'IVD 0- — — - Start Dir 4o/100': 800' MD, 798.7TTVD 1250 End Dir : 1486.87' MD, 1429.32' TVD 1150 2000 Start Dir 50/100' : 3061.17' MD, 2720.441TVD 2500 2750 ']000 0 0 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 West( -)/East(+) (1000 usft/in) KtVIRA17=181L Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S -56i Wellbore: MPU S -56i Design: MPU S-56 wp03 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU S -56i TVD Reference: MPU S-56 As -built RKB @ 63.40usft MD Reference: MPU S-56 As -built RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature 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 Wellbore MPU S -56i Magnetics Model Name Sample Date Design Audit Notes: Version: Vertical Section: BGGM2019 3/15/2020 MPU S-56 wp03 5,999,978.00usft Latitude: 70° 24'37.329 N 566,345.00usft Longitude: 149° 27'35.171 W 0" Grid Convergence: 0.51 ° 5,999,884.82 usfl Latitude: 70° 24'36.487 N 565,478.70 usfl Longitude: 149° 28'0.588 W usfl Ground Level: 36.90 usft Declination Dip Angle Field Strength (°) (°) (nT) 16.01 80.83 57,368.08451493 Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) 26.50 0.00 Plan Sections Site M Pt S Pad Build Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plan: MPU S -56i Inclination Azimuth Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.50 usft Wellhead Elevation Wellbore MPU S -56i Magnetics Model Name Sample Date Design Audit Notes: Version: Vertical Section: BGGM2019 3/15/2020 MPU S-56 wp03 5,999,978.00usft Latitude: 70° 24'37.329 N 566,345.00usft Longitude: 149° 27'35.171 W 0" Grid Convergence: 0.51 ° 5,999,884.82 usfl Latitude: 70° 24'36.487 N 565,478.70 usfl Longitude: 149° 28'0.588 W usfl Ground Level: 36.90 usft Declination Dip Angle Field Strength (°) (°) (nT) 16.01 80.83 57,368.08451493 Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) 26.50 0.00 Plan Sections Dogleg Build Turn Measured +N/ -S +E/ -W Vertical TVD Depth Inclination Azimuth Depth System (usft) (°) (°) (usft) usft 26.50 0.00 0.00 26.50 -36.90 500.00 0.00 0.00 500.00 436.60 800.00 9.00 185.00 798.77 735.37 1,100.00 21.00 185.00 1,088.02 1,024.62 1,486.87 34.90 170.03 1,429.32 1,365.92 3,061.17 34.90 170.03 2,720.44 2,657.04 5,352.92 93.44 300.00 4,076.90 4,013.50 5,577.92 93.44 300.00 4,063.40 4,000.00 5,953.66 90.92 316.73 4,049.02 3,985.62 6,304.61 90.92 316.73 4,043.40 3,980.00 7,113.08 89.95 349.06 4,037.11 3,973.71 14,368.13 89.95 349.06 4,043.40 3,980.00 Tie On Depth: 26.50 +E/ -W Direction (usft) (°) 0.00 349.06 2/10/2020 7:06:49PM Page 2 COMPASS 5000.15 Build 91E Dogleg Build Turn +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -23.42 -2.05 3.00 3.00 0.00 185.00 -100.63 -8.80 4.00 4.00 0.00 0.00 -279.79 4.39 4.00 3.59 -3.87 -33.63 -1,166.99 160.30 0.00 0.00 0.00 0.00 -1,282.00 -1,205.64 5.00 2.55 5.67 122.72 -1,169.70 -1,400.14 0.00 0.00 0.00 0.00 -937.47 -1,693.43 4.50 -0.67 4.45 98.20 -681.96 -1,933.94 0.00 0.00 0.00 0.00 28.19 -2,297.40 4.00 -0.12 4.00 91.54 7,151.35 -3,674.50 0.00 0.00 0.00 0.00 2/10/2020 7:06:49PM Page 2 COMPASS 5000.15 Build 91E Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S -56i Wellbore: MPU S -56i Design: MPU S-56 wp03 Planned Survey Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU S -56i ND Reference: MPU S-56 As -built RKB @ 63.40usft MD Reference: MPU S-56 As -built RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Measured Map Map Vertical +E/ -W Depth Inclination Azimuth Depth TVDss +N/ -S (usft) (°) (usft) (°) (usft) usft (usft) 26.50 0.00 0.00 26.50 -36.90 0.00 100.00 0.00 0.00 100.00 36.60 0.00 200.00 0.00 0.00 200.00 136.60 0.00 300.00 0.00 0.00 300.00 236.60 0.00 400.00 0.00 0.00 400.00 336.60 0.00 500.00 0.00 0.00 500.00 436.60 0.00 Start Dir 3°/100' : 500' MD, 500'TVD -10.06 -2.05 600.00 3.00 185.00 599.95 536.55 -2.61 700.00 6.00 185.00 699.63 636.23 -10.42 800.00 9.00 185.00 798.77 735.37 -23.42 Start Dir 41/100': 800' MD, 798.77'TVD 5,999,745.57 565,469.69 4.00 900.00 13.00 185.00 896.91 833.51 -42.43 1,000.00 17.00 185.00 993.48 930.08 -68.21 1,100.00 21.00 185.00 1,088.02 1,024.62 -100.63 1,200.00 24.43 179.64 1,180.26 1,116.86 -139.17 1,300.00 28.00 175.55 1,269.97 1,206.57 -183.27 1,400.00 31.66 172.33 1,356.71 1,293.31 -232.70 1,486.87 34.90 170.03 1,429.32 1,365.92 -279.79 End Dir : 1486.87' MD, 1429.32' ND 565,528.49 0.00 1,500.00 34.90 170.03 1,440.09 1,376.69 -287.19 1,541.84 34.90 170.03 1,474.40 1,411.00 -310.77 SV5 565,549.28 0.00 -626.31 75.02 5,999,203.89 1,600.00 34.90 170.03 1,522.10 1,458.70 -343.55 1,700.00 34.90 170.03 1,604.11 1,540.71 -399.90 1,800.00 34.90 170.03 1,686.13 1,622.73 -456.26 1,900.00 34.90 170.03 1,768.14 1,704.74 -512.61 2,000.00 34.90 170.03 1,850.15 1,786.75 -568.97 2,027.13 34.90 170.03 1,872.40 1,809.00 -584.25 BPRF -1,026.78 144.34 5,998,810.07 565,632.45 0.00 2,100.00 34.90 170.03 1,932.16 1,868.76 -625.32 2,200.00 34.90 170.03 2,014.18 1,950.78 -681.68 2,300.00 34.90 170.03 2,096.19 2,032.79 -738.03 2,400.00 34.90 170.03 2,178.20 2,114.80 -794.39 2,500.00 34.90 170.03 2,260.21 2,196.81 -850.74 2,553.88 34.90 170.03 2,304.40 2,241.00 -881.10 SV1 2,600.00 34.90 170.03 2,342.23 2,278.83 -907.10 2,700.00 34.90 170.03 2,424.24 2,360.84 -963.45 2,800.00 34.90 170.03 2,506.25 2,442.85 -1,019.81 2,900.00 34.90 170.03 2,588.26 2,524.86 -1,076.16 3,000.00 34.90 170.03 2,670.28 2,606.88 -1,132.52 3,061.17 34.90 170.03 2,720.44 2,657.04 -1,166.99 Start Dir 5°/100' : 3061.17' MD, 2720.44'TVD 3,100.00 33.89 172.96 2,752.49 2,689.09 -1,188.67 3,200.00 31.63 181.21 2,836.62 2,773.22 -1,242.59 2/10/2020 7:06:49PM Page 3 COMPASS 5000.15 Build 91E Map Map +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) -36.90 0.00 5,999,884.82 565,478.70 0.00 0.00 0.00 5,999,884.82 565,478.70 0.00 0.00 0.00 5,999,884.82 565,478.70 0.00 0.00 0.00 5,999,884.82 565,478.70 0.00 0.00 0.00 5,999,884.82 565,478.70 0.00 0.00 0.00 5,999,884.82 565,478.70 0.00 0.00 -0.23 5,999,882.21 565,478.49 3.00 -2.52 -0.91 5,999,874.39 565,477.88 3.00 -10.06 -2.05 5,999,861.38 565,476.86 3.00 -22.61 -3.71 5,999,842.36 565,475.36 4.00 -40.95 -5.97 5,999,816.57 565,473.33 4.00 -65.83 -8.80 5,999,784.12 565,470.78 4.00 -97.13 -10.24 5,999,745.57 565,469.69 4.00 -134.70 -8.28 5,999,701.50 565,472.02 4.00 -178.37 -2.96 5,999,652.12 565,477.78 4.00 -227.91 4.39 5,999,605.10 565,485.54 4.00 -275.54 5.69 5,999,597.72 565,486.91 0.00 -283.05 9.83 5,999,574.18 565,491.26 0.00 -306.99 15.59 5,999,541.46 565,497.30 0.00 -340.26 25.50 5,999,485.20 565,507.70 0.00 -397.47 35.40 5,999,428.94 565,518.10 0.00 -454.68 45.31 5,999,372.68 565,528.49 0.00 -511.89 55.21 5,999,316.41 565,538.89 0.00 -569.10 57.90 5,999,301.15 565,541.71 0.00 -584.62 65.11 5,999,260.15 565,549.28 0.00 -626.31 75.02 5,999,203.89 565,559.68 0.00 -683.52 84.92 5,999,147.63 565,570.08 0.00 -740.73 94.82 5,999,091.37 565,580.47 0.00 -797.94 104.73 5,999,035.11 565,590.87 0.00 -855.15 110.06 5,999,004.80 565,596.47 0.00 -885.98 114.63 5,998,978.85 565,601.27 0.00 -912.36 124.53 5,998,922.59 565,611.66 0.00 -969.57 134.44 5,998,866.33 565,622.06 0.00 -1,026.78 144.34 5,998,810.07 565,632.45 0.00 -1,084.00 154.24 5,998,753.81 565,642.85 0.00 -1,141.21 160.30 5,998,719.39 565,649.21 0.00 -1,176.20 163.55 5,998,697.74 565,652.65 5.00 -1,198.11 166.41 5,998,643.86 565,655.98 5.00 -1,251.59 2/10/2020 7:06:49PM Page 3 COMPASS 5000.15 Build 91E Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S -56i Wellbore: MPU S -56i Design: MPU S-56 wp03 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) (°) (°) (usft) usft Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: +N/ -S (usft) 3,300.00 29.96 190.43 2,922.57 2,859.17 -1,293.39 3,400.00 29.00 200.41 3,009.68 2,946.28 -1,340.69 3,500.00 28.80 210.76 3,097.28 3,033.88 -1,384.14 3,600.00 29.40 220.98 3,184.71 3,121.31 -1,423.39 3,700.00 30.73 230.61 3,271.31 3,207.91 -1,458.15 3,800.00 32.72 239.35 3,356.41 3,293.01 -1,488.16 3,900.00 35.24 247.08 3,439.37 3,375.97 -1,513.18 4,000.00 38.19 253.84 3,519.55 3,456.15 -1,533.04 4,025.40 39.00 255.41 3,539.40 3,476.00 -1,537.24 LA3 -101.20 5,998,346.90 565,390.99 5.00 -1,490.10 4,100.00 41.49 259.71 3,596.35 3,532.95 -1,547.57 4,200.00 45.04 264.85 3,669.18 3,605.78 -1,556.66 4,300.00 48.80 269.37 3,737.49 3,674.09 -1,560.26 4,358.91 51.09 271.79 3,775.40 3,712.00 -1,559.78 UGNU MB -447.67 5,998,330.24 565,044.69 5.00 -1,437.72 4,400.00 52.71 273.39 3,800.75 3,737.35 -1,558.32 4,500.00 56.75 277.00 3,858.49 3,795.09 -1,550.86 4,600.00 60.88 280.30 3,910.27 3,846.87 -1,537.95 4,700.00 65.09 283.33 3,955.69 3,892.29 -1,519.67 4,800.00 69.35 286.16 3,994.40 3,931.00 -1,496.18 4,826.20 70.48 286.88 4,003.40 3,940.00 -1,489.18 SB NA 564,505.03 5.00 -1,181.54 -1,070.91 5,998,521.50 4,900.00 73.66 288.84 4,026.12 3,962.72 -1,467.64 5,000.00 78.00 291.40 4,050.59 3,987.19 -1,434.27 5,100.00 82.36 293.88 4,067.65 4,004.25 -1,396.33 5,105.77 82.62 294.03 4,068.40 4,005.00 -1,394.01 SB NE 564,089.00 0.00 -882.73 -1,419.13 5,998,714.01 5,200.00 86.74 296.31 4,077.14 4,013.74 -1,354.11 5,300.00 91.12 298.72 4,079.01 4,015.61 -1,307.93 5,352.92 93.44 300.00 4,076.90 4,013.50 -1,282.00 End Dir : 5352.92' MD, 4076.9' ND 4.50 -599.05 5,400.00 93.44 300.00 4,074.08 4,010.68 -1,258.50 5,500.00 93.44 300.00 4,068.08 4,004.68 -1,208.59 5,577.92 93.44 300.00 4,063.40 4,000.00 -1,169.70 Start Dir 4.511100': 5577.92' MD, 4063.4'TVD - 9 5/8" x 121/4" 5,600.00 93.30 300.98 4,062.10 3,998.70 -1,158.52 5,700.00 92.64 305.44 4,056.92 3,993.52 -1,103.83 5,800.00 91.97 309.90 4,052.89 3,989.49 -1,042.78 5,900.00 91.29 314.35 4,050.05 3,986.65 -975.76 5,953.66 90.92 316.73 4,049.02 3,985.62 -937.47 End Dir : 5953.66' MD, 4049.02' ND 6,000.00 90.92 316.73 4,048.27 3,984.87 -903.73 6,100.00 90.92 316.73 4,046.67 3,983.27 -830.92 6,200.00 90.92 316.73 4,045.07 3,981.67 -758.12 Halliburton Standard Proposal Report Well Plan: MPU S -56i MPU S-56 As -built RKB @ 63.40usft MPU S-56 As -built RKB @ 63.40usft True Minimum Curvature -1,725.18 5,998,966.09 563,761.67 0.00 -559.90 -1,793.72 5,999,038.28 563,692.51 0.00 -475.41 -1,862.25 5,999,110.48 563,623.35 0.00 -390.92 2/102020 7:06:49PM Page 4 COMPASS 5000.15 Build 91E Map Map +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) 2,859.17 161.33 5,998,593.02 565,651.35 5.00 -1,300.50 148.35 5,998,545.61 565,638.78 5.00 -1,344.48 127.56 5,998,501.99 565,618.37 5.00 -1,383.19 99.12 5,998,462.49 565,590.29 5.00 -1,416.33 63.26 5,998,427.42 565,554.73 5.00 -1,443.65 20.23 5,998,397.04 565,511.98 5.00 -1,464.95 -29.62 5,998,371.58 565,462.35 5.00 -1,480.06 -85.92 5,998,351.23 565,406.23 5.00 -1,488.87 -101.20 5,998,346.90 565,390.99 5.00 -1,490.10 -148.25 5,998,336.16 565,344.04 5.00 -1,491.31 -216.12 5,998,326.47 565,276.26 5.00 -1,487.36 -289.02 5,998,322.24 565,203.39 5.00 -1,477.05 -334.10 5,998,322.32 565,158.32 5.00 -1,468.03 -366.40 5,998,323.50 565,126.01 5.00 -1,460.46 -447.67 5,998,330.24 565,044.69 5.00 -1,437.72 -532.20 5,998,342.41 564,960.05 5.00 -1,409.00 -619.36 5,998,359.92 564,872.74 5.00 -1,374.51 -708.48 5,998,382.63 564,783.43 5.00 -1,334.53 -732.08 5,998,389.42 564,759.78 5.00 -1,323.18 -798.89 5,998,410.38 564,692.78 5.00 -1,289.35 -889.89 5,998,442.94 564,601.50 5.00 -1,239.32 -980.79 5,998,480.08 564,510.28 5.00 -1,184.82 -986.03 5,998,482.36 564,505.03 5.00 -1,181.54 -1,070.91 5,998,521.50 564,419.80 5.00 -1,126.26 -1,159.55 5,998,566.90 564,330.77 5.00 -1,064.10 -1,205.63 5,998,592.42 564,284.47 5.00 -1,029.90 -1,246.33 5,998,615.56 564,243.57 0.00 -999.10 -1,332.78 5,998,664.70 564,156.69 0.00 -933.69 -1,400.14 5,998,703.00 564,089.00 0.00 -882.73 -1,419.13 5,998,714.01 564,069.92 4.50 -868.14 -1,502.66 5,998,767.96 563,985.92 4.50 -798.59 -1,581.73 5,998,828.31 563,906.32 4.50 -723.65 -1,655.85 5,998,894.68 563,831.62 4.50 -643.78 -1,693.43 5,998,932.63 563,793.72 4.50 -599.05 -1,725.18 5,998,966.09 563,761.67 0.00 -559.90 -1,793.72 5,999,038.28 563,692.51 0.00 -475.41 -1,862.25 5,999,110.48 563,623.35 0.00 -390.92 2/102020 7:06:49PM Page 4 COMPASS 5000.15 Build 91E Halliburton HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU S -56i Company: Hilcorp Alaska, LLC TVD Reference: MPU S-56 As -built RKB @ 63.40usft Project: Milne Point MD Reference: MPU S-56 As -built RKB @ 63.40usft Site: M Pt S Pad North Reference: True Well: Plan: MPU S -56i Survey Calculation Method: Minimum Curvature Wellbore: MPU S -56i (°) (°) Design: MPU S-56 wp03 (usft) (usft) 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) 3,980.00 6,304.61 90.92 316.73 4,043.40 3,980.00 -681.95 -1,933.94 5,999,186.00 563,551.00 0.00 -302.54 Start Dir 401100': 6304.61' MD, 4043.4'TVD 6,400.00 90.81 320.55 4,041.96 3,978.56 -610.38 -1,996.95 5,999,257.02 563,487.36 4.00 -220.30 6,500.00 90.70 324.55 4,040.64 3,977.24 -531.02 -2,057.75 5,999,335.84 563,425.88 4.00 -130.85 6,600.00 90.58 328.54 4,039.52 3,976.12 -447.61 -2,112.86 5,999,418.75 563,370.05 4.00 -38.49 6,700.00 90.46 332.54 4,038.61 3,975.21 -360.56 -2,162.02 5,999,505.36 563,320.12 4.00 56.31 6,800.00 90.34 336.54 4,037.91 3,974.51 -270.29 -2,205.00 5,999,595.24 563,276.36 4.00 153.09 6,900.00 90.22 340.54 4,037.42 3,974.02 -177.24 -2,241.58 5,999,687.96 563,238.98 4.00 251.39 7,000.00 90.09 344.54 4,037.16 3,973.76 -81.87 -2,271.58 5,999,783.05 563,208.14 4.00 350.72 7,100.00 89.97 348.54 4,037.10 3,973.70 15.37 -2,294.86 5,999,880.07 563,184.02 4.00 450.61 7,113.08 89.95 349.06 4,037.11 3,973.71 28.20 -2,297.40 5,999,892.87 563,181.36 4.00 463.69 End Dir : 7113.08' MD, 4037.11' TVD 7,200.00 89.95 349.06 4,037.19 3,973.79 113.54 -2,313.90 5,999,978.06 563,164.12 0.00 550.61 7,300.00 89.95 349.06 4,037.28 3,973.88 211.72 -2,332.88 6,000,076.06 563,144.28 0.00 650.61 7,400.00 89.95 349.06 4,037.36 3,973.96 309.90 -2,351.86 6,000,174.06 563,124.44 0.00 750.61 7,500.00 89.95 349.06 4,037.45 3,974.05 408.08 -2,370.84 6,000,272.06 563,104.60 0.00 850.61 7,600.00 89.95 349.06 4,037.54 3,974.14 506.26 -2,389.82 6,000,370.07 563,084.76 0.00 950.61 7,700.00 89.95 349.06 4,037.62 3,974.22 604.45 -2,408.80 6,000,468.07 563,064.92 0.00 1,050.61 7,800.00 89.95 349.06 4,037.71 3,974.31 702.63 -2,427.78 6,000,566.07 563,045.08 0.00 1,150.61 7,900.00 89.95 349.06 4,037.80 3,974.40 800.81 -2,446.76 6,000,664.07 563,025.24 0.00 1,250.61 8,000.00 89.95 349.06 4,037.88 3,974.48 898.99 -2,465.75 6,000,762.08 563,005.40 0.00 1,350.61 8,100.00 89.95 349.06 4,037.97 3,974.57 997.17 -2,484.73 6,000,860.08 562,985.56 0.00 1,450.61 8,200.00 89.95 349.06 4,038.06 3,974.66 1,095.36 -2,503.71 6,000,958.08 562,965.72 0.00 1,550.61 8,300.00 89.95 349.06 4,038.14 3,974.74 1,193.54 -2,522.69 6,001,056.08 562,945.88 0.00 1,650.61 8,400.00 89.95 349.06 4,038.23 3,974.83 1,291.72 -2,541.67 6,001,154.09 562,926.04 0.00 1,750.61 8,500.00 89.95 349.06 4,038.32 3,974.92 1,389.90 -2,560.65 6,001,252.09 562,906.21 0.00 1,850.61 8,600.00 89.95 349.06 4,038.40 3,975.00 1,488.08 -2,579.63 6,001,350.09 562,886.37 0.00 1,950.61 8,700.00 89.95 349.06 4,038.49 3,975.09 1,586.27 -2,598.62 6,001,448.09 562,866.53 0.00 2,050.61 8,800.00 89.95 349.06 4,038.58 3,975.18 1,684.45 -2,617.60 6,001,546.10 562,846.69 0.00 2,150.61 8,900.00 89.95 349.06 4,038.66 3,975.26 1,782.63 -2,636.58 6,001,644.10 562,826.85 0.00 2,250.61 9,000.00 89.95 349.06 4,038.75 3,975.35 1,880.81 -2,655.56 6,001,742.10 562,807.01 0.00 2,350.61 9,100.00 89.95 349.06 4,038.84 3,975.44 1,978.99 -2,674.54 6,001,840.10 562,787.17 0.00 2,450.61 9,200.00 89.95 349.06 4,038.92 3,975.52 2,077.18 -2,693.52 6,001,938.11 562,767.33 0.00 2,550.61 9,300.00 89.95 349.06 4,039.01 3,975.61 2,175.36 -2,712.50 6,002,036.11 562,747.49 0.00 2,650.61 9,400.00 89.95 349.06 4,039.10 3,975.70 2,273.54 -2,731.48 6,002,134.11 562,727.65 0.00 2,750.61 9,500.00 89.95 349.06 4,039.18 3,975.78 2,371.72 -2,750.47 6,002,232.11 562,707.81 0.00 2,850.61 9,600.00 89.95 349.06 4,039.27 3,975.87 2,469.90 -2,769.45 6,002,330.12 562,687.97 0.00 2,950.61 9,700.00 89.95 349.06 4,039.36 3,975.96 2,568.09 -2,788.43 6,002,428.12 562,668.13 0.00 3,050.61 9,800.00 89.95 349.06 4,039.44 3,976.04 2,666.27 -2,807.41 6,002,526.12 562,648.29 0.00 3,150.61 9,900.00 89.95 349.06 4,039.53 3,976.13 2,764.45 -2,826.39 6,002,624.12 562,628.45 0.00 3,250.61 10,000.00 89.95 349.06 4,039.61 3,976.21 2,862.63 -2,845.37 6,002,722.13 562,608.61 0.00 3,350.61 10,100.00 89.95 349.06 4,039.70 3,976.30 2,960.81 -2,864.35 6,002,820.13 562,588.77 0.00 3,450.61 10,200.00 89.95 349.06 4,039.79 3,976.39 3,059.00 -2,883.34 6,002,918.13 562,568.93 0.00 3,550.60 10,300.00 89.95 349.06 4,039.87 3,976.47 3,157.18 -2,902.32 6,003,016.13 562,549.09 0.00 3,650.60 10,400.00 89.95 349.06 4,039.96 3,976.56 3,255.36 -2,921.30 6,003,114.14 562,529.26 0.00 3,750.60 2/10/2020 7:06:49PM Page 5 COMPASS 5000.15 Build 91E Halliburton HALLIBBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU S -56i Company: Hilcorp Alaska, LLC TVD Reference: MPU S-56 As -built RKB @ 63.40usft Project: Milne Point MD Reference: MPU S-56 As -built RKB @ 63.40usft Site: M Pt S Pad North Reference: True Well: Plan: MPU S -56i Survey Calculation Method: Minimum Curvature Wellbore: MPU S -56i Design: MPU S-56 wp03 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) 3,976.65 10,500.00 89.95 349.06 4,040.05 3,976.65 3,353.54 -2,940.28 6,003,212.14 562,509.42 0.00 3,850.60 10,600.00 89.95 349.06 4,040.13 3,976.73 3,451.72 -2,959.26 6,003,310.14 562,489.58 0.00 3,950.60 10,700.00 89.95 349.06 4,040.22 3,976.82 3,549.91 -2,978.24 6,003,408.14 562,469.74 0.00 4,050.60 10,800.00 89.95 349.06 4,040.31 3,976.91 3,648.09 -2,997.22 6,003,506.15 562,449.90 0.00 4,150.60 10,900.00 89.95 349.06 4,040.39 3,976.99 3,746.27 -3,016.20 6,003,604.15 562,430.06 0.00 4,250.60 11,000.00 89.95 349.06 4,040.48 3,977.08 3,844.45 -3,035.19 6,003,702.15 562,410.22 0.00 4,350.60 11,100.00 89.95 349.06 4,040.57 3,977.17 3,942.63 -3,054.17 6,003,800.15 562,390.38 0.00 4,450.60 11,200.00 89.95 349.06 4,040.65 3,977.25 4,040.82 -3,073.15 6,003,898.16 562,370.54 0.00 4,550.60 11,300.00 89.95 349.06 4,040.74 3,977.34 4,139.00 -3,092.13 6,003,996.16 562,350.70 0.00 4,650.60 11,400.00 89.95 349.06 4,040.83 3,977.43 4,237.18 -3,111.11 6,004,094.16 562,330.86 0.00 4,750.60 11,500.00 89.95 349.06 4,040.91 3,977.51 4,335.36 -3,130.09 6,004,192.16 562,311.02 0.00 4,850.60 11,600.00 89.95 349.06 4,041.00 3,977.60 4,433.54 -3,149.07 6,004,290.17 562,291.18 0.00 4,950.60 11,700.00 89.95 349.06 4,041.09 3,977.69 4,531.73 -3,168.05 6,004,388.17 562,271.34 0.00 5,050.60 11,800.00 89.95 349.06 4,041.17 3,977.77 4,629.91 -3,187.04 6,004,486.17 562,251.50 0.00 5,150.60 11,900.00 89.95 349.06 4,041.26 3,977.86 4,728.09 -3,206.02 6,004,584.17 562,231.66 0.00 5,250.60 12,000.00 89.95 349.06 4,041.35 3,977.95 4,826.27 -3,225.00 6,004,682.18 562,211.82 0.00 5,350.60 12,100.00 89.95 349.06 4,041.43 3,978.03 4,924.45 -3,243.98 6,004,780.18 562,191.98 0.00 5,450.60 12,200.00 89.95 349.06 4,041.52 3,978.12 5,022.64 -3,262.96 6,004,878.18 562,172.14 0.00 5,550.60 12,300.00 89.95 349.06 4,041.61 3,978.21 5,120.82 -3,281.94 6,004,976.18 562,152.31 0.00 5,650.60 12,400.00 89.95 349.06 4,041.69 3,978.29 5,219.00 -3,300.92 6,005,074.19 562,132.47 0.00 5,750.60 12,500.00 89.95 349.06 4,041.78 3,978.38 5,317.18 -3,319.91 6,005,172.19 562,112.63 0.00 5,850.60 12,600.00 89.95 349.06 4,041.87 3,978.47 5,415.36 -3,338.89 6,005,270.19 562,092.79 0.00 5,950.60 12,700.00 89.95 349.06 4,041.95 3,978.55 5,513.55 -3,357.87 6,005,368.19 562,072.95 0.00 6,050.60 12,800.00 89.95 349.06 4,042.04 3,978.64 5,611.73 -3,376.85 6,005,466.20 562,053.11 0.00 6,150.60 12,900.00 89.95 349.06 4,042.13 3,978.73 5,709.91 -3,395.83 6,005,564.20 562,033.27 0.00 6,250.60 13,000.00 89.95 349.06 4,042.21 3,978.81 5,808.09 -3,414.81 6,005,662.20 562,013.43 0.00 6,350.60 13,100.00 89.95 349.06 4,042.30 3,978.90 5,906.27 -3,433.79 6,005,760.20 561,993.59 0.00 6,450.60 13,200.00 89.95 349.06 4,042.39 3,978.99 6,004.46 -3,452.77 6,005,858.21 561,973.75 0.00 6,550.60 13,300.00 89.95 349.06 4,042.47 3,979.07 6,102.64 -3,471.76 6,005,956.21 561,953.91 0.00 6,650.60 13,400.00 89.95 349.06 4,042.56 3,979.16 6,200.82 -3,490.74 6,006,054.21 561,934.07 0.00 6,750.60 13,500.00 89.95 349.06 4,042.65 3,979.25 6,299.00 -3,509.72 6,006,152.21 561,914.23 0.00 6,850.60 13,600.00 89.95 349.06 4,042.73 3,979.33 6,397.18 -3,528.70 6,006,250.22 561,894.39 0.00 6,950.60 13,700.00 89.95 349.06 4,042.82 3,979.42 6,495.37 -3,547.68 6,006,348.22 561,874.55 0.00 7,050.60 13,800.00 89.95 349.06 4,042.91 3,979.51 6,593.55 -3,566.66 6,006,446.22 561,854.71 0.00 7,150.60 13,900.00 89.95 349.06 4,042.99 3,979.59 6,691.73 -3,585.64 6,006,544.22 561,834.87 0.00 7,250.60 14,000.00 89.95 349.06 4,043.08 3,979.68 6,789.91 -3,604.63 6,006,642.23 561,815.03 0.00 7,350.60 14,100.00 89.95 349.06 4,043.17 3,979.77 6,888.09 -3,623.61 6,006,740.23 561,795.20 0.00 7,450.60 14,200.00 89.95 349.06 4,043.25 3,979.85 6,986.28 -3,642.59 6,006,838.23 561,775.36 0.00 7,550.60 14,300.00 89.95 349.06 4,043.34 3,979.94 7,084.46 -3,661.57 6,006,936.23 561,755.52 0.00 7,650.60 14,368.13 89.95 349.06 4,043.40 3,980.00 7,151.35 -3,674.50 6,007,003.00 561,742.00 0.00 7,718.73 Total Depth: 14368.13' MD, 4043.4' TVD 2/102020 7:06:49PM Page 6 COMPASS 5000.95 Build 91E HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Plan: MPU S -56i Wellbore: MPU S -56i Design: MPU S-56 wp03 Targets Target Name hit/miss target Shape MPU S-56 wp03 CP1 plan hits target center Point MPU S-56 wp03 Toe plan hits target center Point MPU S-56 wp03 CP2 plan hits target center Point Casing Points Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU S -56i TVD Reference: MPU S-56 As -built RKB @ 63.40usft MD Reference: MPU S-56 As -built RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting (°) (°) (usft) (usft) (usft) (usft) (usft) 0.00 0.00 4,063.40 -1,169.70 -1,400.14 5,998,703.00 564,089.00 0.00 0.00 4,043.40 7,151.35 -3,674.50 6,007,003.00 561,742.00 0.00 0.00 4,043.40 -681.96 -1,933.94 5,999,186.00 563,551.00 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name ("1 C') 5,577.92 4,063.40 9 5/8" x 12 1/4" 9-5/8 12-1/4 14,368.13 4,043.40 6 5/8" x 8 1/2" 6-5/8 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (°) 4,025.40 3,539.40 LA3 4,358.91 3,775.40 UGNU MB 2,027.13 1,872.40 BPRF 5,105.77 4,068.40 SB_NE 4,826.20 4,003.40 SB_NA 1,541.84 1,474.40 SV5 2,553.88 2,304.40 SV1 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 Start Dir 3°/100' : 500' MD, 500'TVD 800.00 798.77 -23.42 -2.05 Start Dir 41/100' : 800' MD, 798.77'TVD 1,486.87 1,429.32 -279.79 4.39 End Dir : 1486.87' MD, 1429.32' TVD 3,061.17 2,720.44 -1,166.99 160.30 Start Dir 5°/100' : 3061.17' MD, 2720.44'TVD 5,352.92 4,076.90 -1,282.00 -1,205.63 End Dir : 5352.92' MD, 4076.9' TVD 5,577.92 4,063.40 -1,169.70 -1,400.14 Start Dir 4.5°/100' : 5577.92' MD, 4063.4'TVD 5,953.66 4,049.02 -937.47 -1,693.43 End Dir : 5953.66' MD, 4049.02' TVD 6,304.61 4,043.40 -681.95 -1,933.94 Start Dir 40/100' : 6304.61' MD, 4043.4'TVD 7,113.08 4,037.11 28.20 -2,297.40 End Dir : 7113.08' MD, 4037.11' TVD 14,368.13 4,043.40 7,151.35 -3,674.50 Total Depth : 14368.13' MD, 4043.4' TVD 2/10/2020 7:06.49PM Page 7 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S -56i MPU S -56i MPU S-56 wp03 Sperry Drilling Services Clearance Summary Anticollision Report 10 February, 2020 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S -56i - MPU S-56 wp03 Well Coordinates: 5,999,884.82 N, 565,478.70 E (700 24' 36.49" N, 149° 28' 00.59" W) Datum Height: MPU S-56 As -built RKB @ 63.40usft Scan Range: 26.50 to 5,577.92 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91E Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Hilcorp Alaska, LLC Milne Point Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S -56i - MPU S-56 Wp03 Scan Range: 26.50 to 5,577.92 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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 M Pt H Pad M Pt S Pad MPS -06 - MPS -06 - MPS -06 4,276.50 136.47 4,276.50 71.24 4,369.04 2.092 Clearance Factor Pass - MPS -06 - MPS -06 - MPS -06 4,326.50 123.46 4,326.50 68.30 4,406.33 2.238 Ellipse Separation Pass - MPS -06 - MPS -06 - MPS -06 4,384.19 117.45 4,384.19 78.67 4,448.15 3.029 Centre Distance Pass - MPS -08 - MPS -08 - MPS -08 3,501.50 170.92 3,501.50 126.03 3,728.49 3.808 Clearance Factor Pass - MPS -08 - MPS -08 - MPS -08 3,626.50 142.60 3,626.50 109.88 3,824.70 4.358 Ellipse Separation Pass - MPS -08 - MPS -08 - MPS -08 3,650.29 141.60 3,650.29 110,53 3,839.25 4.557 Centre Distance Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 3,501.50 170.92 3,501.50 126.03 3,728.49 3.808 Clearance Factor Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 3,626.50 142.60 3,626.50 109.88 3,824.70 4.358 Ellipse Separation Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 3,650.29 141.60 3,650.29 110.53 3,839.25 4.557 Centre Distance Pass - MPS -13 - MPS -13 - MPS -13 2,066.40 387.97 2,066.40 374.07 2,175.61 27.925 Centre Distance Pass - MPS -13 - MPS -13 - MPS -13 2,076.50 387.99 2,076.50 374.04 2,185.14 27.825 Ellipse Separation Pass - MPS -13 - MPS -13 - MPS -13 4,926.50 509.28 4,926.50 456.98 4,561.36 9.738 Clearance Factor Pass - MPS -14 - MPS -14 - MPS -14 1,429.63 262.77 1,429.63 250.77 1,556.28 21.887 Ellipse Separation Pass - MPS -14 - MPS -14 - MPS -14 1,701.50 317.13 1,701.50 300.11 1,765.31 18.630 Clearance Factor Pass - MPS -17 - MPS -17 - MPS -17 273.25 377.56 273.25 374.43 275.75 120.789 Centre Distance Pass - MPS -17 - MPS -17 - MPS -17 301.50 377.63 301.50 374.36 302.28 115.422 Ellipse Separation Pass - MPS -17 - MPS -17 - MPS -17 1,626.50 571.98 1,626.50 561.89 1,547.29 56.665 Clearance Factor Pass - MPS -17 - MPS -171-1 - MPS -171-1 273.25 377.56 273.25 374.56 275.75 126.039 Centre Distance Pass - MPS -17 - MPS -171-1 - MPS -171-1 301.50 377.63 301.50 374.49 302.28 120.206 Ellipse Separation Pass - MPS -17 -MPS -171 -1 -MPS -171-1 1,626.50 571.98 1,626.50 562.02 1,547.29 57.406 Clearance Factor Pass - MPS -20 - MPS -20 - MPS -20 514.41 329.12 514.41 323.68 524.26 60.416 Centre Distance Pass - MPS -20 - MPS -20 - MPS -20 526.50 329.15 526.50 323.67 535.42 60.045 Ellipse Separation Pass - MPS -20 - MPS -20 - MPS -20 1,226.50 409.49 1,226.50 400.85 1,212.20 47.432 Clearance Factor Pass - MPS -21 - MPS -21 - MPS -21 571.23 313.23 571.23 309.11 586.83 76.034 Centre Distance Pass - MPS -21 - MPS -21 - MPS -21 576.50 313.24 576.50 309.08 591.84 75.352 Ellipse Separation Pass - MPS -21 - MPS -21 - MPS -21 1,076.50 388.72 1,076.50 380.15 1,056.47 45.343 Clearance Factor Pass - 10 February, 2020 - 19:07 Page 2 of 9 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S -56i - MPU S-56 wp03 Scan Range: 26.50 to 5,577.92 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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 MPS -22 -MPS -22 -MPS -22 1,115.13 269.35 1,115.13 259.98 1,179.71 28.737 Centre Distance Pass - MPS -22 -MPS -22 -MPS -22 1,126.50 269.40 1,126.50 259.95 1,190.21 28.508 Ellipse Separation Pass - MPS -22 -MPS -22 -MPS -22 5,577.92 1,098.71 5,577.92 1,042.46 4,875.02 19.533 Clearance Factor Pass - MPS -23 - MPS -23 - MPS -23 5,476.50 191.92 5,476.50 129.95 6,619.53 3.097 Clearance Factor Pass - MPS -23 -MPS -23 - MPS -23 5,577.92 148.77 5,577.92 109.50 6,577.60 3.789 Ellipse Separation Pass - MPS -23 - MPS -231-1 - MPS -23L1 5,526.50 124.10 5,526.50 70.34 6,588.91 2.308 Clearance Factor Pass - MPS -23 - MPS -23L1 - MPS -231-1 5,551.50 112.14 5,551.50 65.92 6,576.19 2.426 Ellipse Separation Pass - MPS -23 - MPS -231-1 - MPS -231-1 5,577.92 103.12 5,577.92 66.19 6,564.02 2.792 Centre Distance Pass - MPS -24 - MPS -24 - MPS -24 669.84 271.78 669.84 264.74 687.61 38.615 Centre Distance Pass - MPS -24 - MPS -24 - MPS -24 676.50 271.79 676.50 264.73 694.12 38.507 Ellipse Separation Pass - MPS -24 - MPS -24 - MPS -24 5,577.92 858.04 5,577.92 772.90 5,610.54 10.078 Clearance Factor Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 669.84 271.78 669.84 264.74 687.61 38.615 Centre Distance Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 676.50 271.79 676.50 264.73 694.12 38.507 Ellipse Separation Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 5,577.92 1,004.45 5,577.92 888.83 5,033.00 8.688 Clearance Factor Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 669.84 271.78 669.84 264.74 687.61 38.615 Centre Distance Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 676.50 271.79 676.50 264.73 694.12 38.507 Ellipse Separation Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 5,577.92 858.04 5,577.92 772.75 5,610.54 10.060 Clearance Factor Pass - MPS -25 - MPS -25 - MPS -25 530.20 257.04 530.20 253.17 534.92 66.440 Centre Distance Pass - MPS -25 - MPS -25 - MPS -25 551.50 257.08 551.50 253.08 556.23 64.276 Ellipse Separation Pass - MPS -25 - MPS -25 - MPS -25 1,026.50 310.68 1,026.50 303.13 1,010.19 41.148 Clearance Factor Pass - MPS -25 - MPS -251-1 - MPS -251-1 530.20 257.04 530.20 253.17 534.92 66.440 Centre Distance Pass - MPS -25 - MPS -251-1 - MPS -25L1 551.50 257.08 551.50 253.08 556.23 64.275 Ellipse Separation Pass - MPS -25 -MPS -251 -1 -MPS -251-1 1,026.50 310.68 1,026.50 303.13 1,010.19 41.145 Clearance Factor Pass - MPS -26 - MPS -26 - MPS -26 1,582.36 108.00 1,582.36 97.86 1,640.15 10.655 Ellipse Separation Pass - MPS -26 -MPS -26 -MPS -26 1,801.50 143.40 1,801.50 127.32 1,836.32 8.914 Clearance Factor Pass - MPS -27 - MPS -27 - MPS -27 26.50 229.20 26.50 227.36 30.38 124.014 Centre Distance Pass - MPS -27 - MPS -27 - MPS -27 101.50 229.32 101.50 227.30 104.71 113.603 Ellipse Separation Pass - MPS -27 -MPS -27 -MPS -27 1,126.50 273.89 1,126.50 265.54 1,128.29 32.812 Clearance Factor Pass - MPS -27 - MPS -271-1 - MPS -27L1 26.50 229.20 26.50 227.36 30.38 124.014 Centre Distance Pass - MPS -27 - MPS -27L1 - MPS -271-1 101.50 229.32 101.50 227.30 104.71 113.603 Ellipse Separation Pass - 10 February, 2020 - 19:07 Page 3 of 9 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 598.87 192.29 598.87 188.15 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 46.420 Centre Distance Pass - MPS -29 - MPS -29 - MPS -29 626.50 192.45 Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S-561 - MPU S-56 Wp03 635.45 44.345 Ellipse Separation Pass - MPS -29 - MPS -29 - MPS -29 901.50 Scan Range: 26.50 to 5,577.92 usft. Measured Depth. 901.50 216.33 891.92 33.247 Clearance Factor Pass - MPS -29 - MPS -29L1 - MPS -291-1 598.87 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 608.25 46.420 Centre Distance Pass - MPS -29 - MPS -291-1 - MPS -291-1 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Pass - Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 20.942 Centre Distance Pass - MPS -27 -MPS -271 -1 -MPS -271-1 1,126.50 273.89 1,126.50 265.55 1,128.29 32.835 Clearance Factor Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 26.50 229.20 26.50 227.36 30.38 124.014 Centre Distance Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 151.50 229.52 151.50 227.29 154.31 103.098 Ellipse Separation Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 1,101.50 266.27 1,101.50 257.63 1,108.44 30.812 Clearance Factor Pass - M PS -28 - MPS -28 - MPS -28 842.33 212.06 842.33 204.08 872.75 26.564 Centre Distance Pass - MPS -28 - MPS -28 - MPS -28 851.50 212.08 851.50 204.06 882.49 26.450 Ellipse Separation Pass - MPS -28 - MPS -28 - MPS -28 976.50 217.37 976.50 208.88 1,005.28 25.599 Clearance Factor Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 842.33 212.06 842.33 204.08 872.75 26.564 Centre Distance Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 851.50 212.08 851.50 204.06 882.49 26.450 Ellipse Separation Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 976.50 217.37 976.50 208.88 1,005.28 25.599 Clearance Factor Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 842.33 212.06 842.33 204.08 872.75 26.564 Centre Distance Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 851.50 212.08 851.50 204.06 862.49 26.450 Ellipse Separation Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 976.50 217.37 976.50 208.88 1,005.28 25.599 Clearance Factor Pass - MPS -29 - MPS -29 - MPS -29 598.87 192.29 598.87 188.15 608.25 46.420 Centre Distance Pass - MPS -29 - MPS -29 - MPS -29 626.50 192.45 626.50 188.11 635.45 44.345 Ellipse Separation Pass - MPS -29 - MPS -29 - MPS -29 901.50 223.04 901.50 216.33 891.92 33.247 Clearance Factor Pass - MPS -29 - MPS -29L1 - MPS -291-1 598.87 192.29 598.87 188.15 608.25 46.420 Centre Distance Pass - MPS -29 - MPS -291-1 - MPS -291-1 626.50 192.45 626.50 188.11 635.45 44.345 Ellipse Separation Pass - MPS -29 - MPS -291-1 - MPS -29L1 901.50 223.04 901.50 216.33 891.92 33.247 Clearance Factor Pass - MPS -30 - MPS -30 - MPS -30 702.22 180.21 702.22 171.60 718.34 20.942 Centre Distance Pass - MPS -30 - MPS -30 - MPS -30 726.50 180.28 726.50 171.50 742.77 20.533 Ellipse Separation Pass - MPS -30 - MPS -30 - MPS -30 876.50 184.87 876.50 175.33 894.78 19.385 Clearance Factor Pass - MPS -3I -MPS -3I -MPS -31 1,097.64 141.81 1,097.64 134.87 1,140.87 20.443 Centre Distance Pass - MPS -3I -MPS -3I -MPS -31 1,101.50 141.82 1,101.50 134.87 1,144.76 20.398 Ellipse Separation Pass - MPS -3I -MPS -3I -MPS -31 1,426.50 181.63 1,426.50 171.49 1,465.33 17.914 Clearance Factor Pass - MPS -32 - MPS -32 - MPS -32 597.98 151.96 597.98 145.04 610.77 21.943 Centre Distance Pass - MPS -32 - MPS -32 - MPS -32 626.50 152.12 626.50 144.86 639.09 20.977 Ellipse Separation Pass - MPS -32 - MPS -32 - MPS -32 751.50 158.69 751.50 150.54 759.99 19.453 Clearance Factor Pass - MPS -33 - MPS -33 - MPS -33 284.57 138.77 264.57 135.86 286.87 47.787 Centre Distance Pass - MPS -33 - MPS -33 - MPS -33 526.50 138.88 526.50 134.94 528.99 35.248 Ellipse Separation Pass - MPS -33 -MPS -33 -MPS -33 5,577.92 1,562.09 5,577.92 1,459.92 4,210.29 15.289 Clearance Factor Pass - 10 February, 2020 - 19:07 Page 4 of 9 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 702.62 104.96 702.62 99.46 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 19.084 Ellipse Separation Pass - MPS -34 - MPS -341-1 - MPS -34L1 826.50 116.21 Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S-561 - MPU S-56 Wp03 109.41 838.85 17.089 Clearance Factor Pass - MPS34 - MPS -341-2 - MPS -341-2 Scan Range: 26.50 to 5,577.92 usft. Measured Depth. 104.96 702.62 99.46 723.65 19.084 Ellipse Separation Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft MPS -34 - MPS -341-2 - MPS -341-2 826.50 116.21 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on MPS -35 - MPS -35 - MPS -35 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 776.50 76.09 MPS33 - MPS -33A - MPS -33A 284.57 138.77 284.57 135.86 293.18 47.787 Centre Distance Pass - MPS -33 - MPS -33A - MPS -33A 526.50 138.88 526.50 134.94 535.30 35.248 Ellipse Separation Pass - MPS33-MPS-33A-MPS-33A 5,577.92 1,306.31 5,577.92 1,214.51 4,495.31 14.229 Clearance Factor Pass - MPS -34 - MPS -34 - MPS -34 702.62 104.96 702.62 99.46 723.65 19.084 Ellipse Separation Pass - MPS -34 - MPS -34 - MPS -34 826.50 116.21 826.50 109.41 838.85 17.089 Clearance Factor Pass - MPS -34 - MPS -341-1 - MPS -341-1 702.62 104.96 702.62 99.46 723.65 19.084 Ellipse Separation Pass - MPS -34 - MPS -341-1 - MPS -34L1 826.50 116.21 826.50 109.41 838.85 17.089 Clearance Factor Pass - MPS34 - MPS -341-2 - MPS -341-2 702.62 104.96 702.62 99.46 723.65 19.084 Ellipse Separation Pass - MPS -34 - MPS -341-2 - MPS -341-2 826.50 116.21 826.50 109.41 838.85 17.089 Clearance Factor Pass - MPS -35 - MPS -35 - MPS -35 708.05 79.85 708.05 73.19 727.09 12.000 Ellipse Separation Pass - MPS -35 - MPS -35 - MPS -35 776.50 83.26 776.50 76.09 793.35 11.610 Clearance Factor Pass - MPS -35 - MPS-35PB1 - MPS-35PI31 708.05 79.85 708.05 73.19 727.09 12.000 Ellipse Separation Pass - MPS -35 - MPS-35PB1 - MPS-35PB1 776.50 83.26 776.50 76.09 793.35 11.610 Clearance Factor Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 708.05 79.85 708.05 73.19 727.09 12.000 Ellipse Separation Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 776.50 83.26 776.50 76.09 793.35 11.610 Clearance Factor Pass - MPS -37 - MPS -37 - MPS -37 127.12 74.85 127.12 72.88 135.61 38.027 Centre Distance Pass - MPS -37 - MPS -37 - MPS -37 251.50 75.15 251.50 72.33 259.51 26.604 Ellipse Separation Pass - MPS -37 - MPS -37 - MPS -37 901.50 117.05 901.50 109.18 901.47 14.874 Clearance Factor Pass - MPS -39 - MPS -39 - MPS -39 104.86 44.99 104.86 43.18 106.89 24.870 Centre Distance Pass - MPS -39 - MPS -39 - MPS -39 176.50 45.27 176.50 42.99 178.26 19.863 Ellipse Separation Pass - MPS -39 - MPS -39 - MPS -39 526.50 57.67 526.50 52.79 524.18 11.827 Clearance Factor Pass - MPS -41 - MPS -41 - MPS -41 453.61 13.16 453.61 7.54 461.75 2.343 Centre Distance Pass - MPS -41 - MPS -41 - MPS41 501.50 13.35 501.50 7.41 509.54 2.248 Ellipse Separation Pass - MPS -41 - MPS -41 - MPS -41 526.50 13.66 526.50 7.57 534.47 2.243 Clearance Factor Pass - MPS-4I-MPS41A-MPS-41A 453.61 13.16 453.61 7.54 461.75 2.343 Centre Distance Pass - MPS -4I -MPS -41A -MPS -41A 501.50 13.35 501.50 7.41 509.54 2.248 Ellipse Separation Pass - MPS -4I -MPS -41A -MPS -41A 526.50 13.66 526.50 7.57 534.47 2.243 Clearance Factor Pass - MPS -41 -MPS-41APB1-MPS-41APB1 453.61 13.16 453.61 7.54 461.75 2.343 Centre Distance Pass - MPS-41-MPS-41APB1-MPS41APB1 501.50 13.35 501.50 7.41 509.54 2.248 Ellipse Separation Pass - MPS41-MPS-41APB1-MPS41APB1 526.50 13.66 526.50 7.57 534.47 2.243 Clearance Factor Pass - 10 February, 2020 - 19:07 Page 5 of 9 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 26.50 30.11 26.50 28.70 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 21.329 Centre Distance Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 51.50 30.16 Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S -56i - MPU S-56 wp03 51.39 20.362 Ellipse Separation Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 4,401.50 Scan Range: 26.50 to 5,577.92 usft. Measured Depth. 4,401.50 185.24 4,654.06 6.386 Clearance Factor Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 - a 679.88 Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 679.16 5.510 Ellipse Separation Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 - a 701.50 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Pass - Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a MPS -41 - MPS-41APB2 - MPS-41APB2 453.61 13.16 453.61 7.54 461.75 2.343 Centre Distance Pass - MPS -41 - MPS-41APB2 - MPS-41APB2 501.50 13.35 501.50 7.41 509.54 2.248 Ellipse Separation Pass - MPS -41 - MPS-41APB2 - MPS-41APB2 526.50 13.66 526.50 7.57 534.47 2.243 Clearance Factor Pass - MPS -43 - MPS -43 - MPS -43 260.87 13.26 260.87 9.78 268.78 3.811 Centre Distance Pass - MPS -43 - MPS -43 - MPS43 276.50 13.35 276.50 9.69 284.32 3.655 Ellipse Separation Pass - MPS -43 - MPS -43 - MPS -43 301.50 13.91 301.50 9.98 309.14 3.538 Clearance Factor Pass - MPU S-203 - MPU S-203 - MPU S-203 26.50 30.11 26.50 28.70 26.70 21.329 Centre Distance Pass - MPU S-203 - MPU S-203 - MPU S-203 51.50 30.16 51.50 28.67 51.39 20.362 Ellipse Separation Pass - MPU S-203 - MPU S-203 - MPU S-203 4,401.50 219.63 4,401.50 185.24 4,654.06 6.386 Clearance Factor Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 26.50 30.11 26.50 28.70 26.70 21.329 Centre Distance Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 51.50 30.16 51.50 28.67 51.39 20.362 Ellipse Separation Pass - MPU S-203 - MPU S-203PB1 - MPU S -203P61 4,401.50 219.63 4,401.50 185.24 4,654.06 6.386 Clearance Factor Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 26.50 30.11 26.50 28.70 26.70 21.329 Centre Distance Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 51.50 30.16 51.50 28.67 51.39 20.362 Ellipse Separation Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 4,401.50 219.63 4,401.50 185.24 4,654.06 6.386 Clearance Factor Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 - a 679.88 23.54 679.88 19.26 679.16 5.510 Ellipse Separation Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 - a 701.50 23.71 701.50 19.34 700.00 5.427 Clearance Factor Pass - Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a 617.33 59.99 617.33 55.81 618.10 14.346 Centre Distance Pass - Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a 701.50 60.19 701.50 55.55 702.71 12.987 Ellipse Separation Pass - Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a 4,876.50 571.27 4,876.50 515.67 5,358.98 10.276 Clearance Factor Pass - Proposal Plan: MPU S-206 - MPU S-206 - UGNU#6 -: 635.15 31.89 635.15 27.55 638.35 7.361 Ellipse Separation Pass - Proposal Plan: MPU S-206 - MPU S-206 - UGNU#6 -: 651.50 32.10 651.50 27.67 654.34 7.251 Clearance Factor Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 578.09 54.10 578.09 50.07 582.26 13.427 Ellipse Separation Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 651.50 57.12 651.50 52.66 653.04 12.821 Clearance Factor Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 552.87 72.69 552.87 68.80 556.41 18.667 Ellipse Separation Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 651.50 76.05 651.50 71.61 651.58 17.108 Clearance Factor Pass - Proposal Plan: MPU S-209 - MPU S-209 - MPU S-209 435.84 90.37 435.84 87.07 438.72 27.392 Centre Distance Pass - Proposal Plan: MPU S-209 - MPU S-209 - MPU S-209 476.50 90.45 476.50 86.95 479.16 25.823 Ellipse Separation Pass - Proposal Plan: MPU S-209 - MPU S-209 - MPU S-209 651.50 95.69 651.50 91.35 649.42 22.029 Clearance Factor Pass - Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 351.50 105.82 351.50 102.92 354.20 36.566 Centre Distance Pass - 10 February, 2020 - 19:07 Page 6 of 9 COMPASS HALLIBURTON Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Clearance Summary Based on Reference Design: M Pt S Pad - Plan: MPU S-561 - MPU S -56i - MPU S-56 wp03 Separation Warning usft Scan Range: 26.50 to 5,577.92 usft. Measured Depth. 428.78 32.677 Ellipse Separation Pass - Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft 279.76 35.797 Centre Distance Measured Minimum @Measured Ellipse Site Name Depth Distance Depth Separation Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 426.50 105.95 426.50 102.71 Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 751.50 117.96 751.50 113.01 RIG: MPU S-57 - MPU S-57 - MPU S-57 280.36 92.20 280.36 89.62 RIG: MPU S-57 - MPU S-57 - MPU S-57 301.50 92.20 301.50 89.54 RIG: MPU S-57 - MPU S-57 - MPU S-57 376.50 119.42 376.50 115.20 RIG: MPU S-57 - MPU S-57 - MPU S-57 wp03 230.36 92.20 230.36 89.82 RIG: MPU S-57 - MPU S-57 - MPU S-57 wp03 276.50 92.28 276.50 89.72 RIG: MPU S-57 - MPU S-57 - MPU S-57 wp03 3,226.50 170.42 3,226.50 140.49 Survey tool program From To Survey/Plan (usft) (usft) 26.50 900.00 MPU S-56 wp03 900.00 5,577.92 MPU S-56 wp03 5,577.92 14,368.13 MPU S-56 wp03 Ellipse error terms are correlated across survey tool tie -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 Separation). All station coordinates were calculated using the Minimum Curvature method Hilcorp Alaska, LLC Milne Point @Measured Clearance Summary Based on Depth Factor Minimum Separation Warning usft 428.78 32.677 Ellipse Separation Pass - 743.01 23.790 Clearance Factor Pass - 279.76 35.797 Centre Distance Pass - 300.00 34.610 Ellipse Separation Pass - 300.00 28.276 Clearance Factor Pass - 229.76 38.830 Centre Distance Pass - 275.32 36.067 Ellipse Separation Pass - 3,242.21 5.693 Clearance Factor Pass - Survey Tool 3_Gyro-GC_Csg 3 MWD+IFR2+MS+Sag 3_M WD+I FR2+M S+Sag 10 February, 2020 - 19:07 Page 7 of 9 COMPASS HALLIBURTON Project: Milne Point REFERENCE INFORMATION WELL DETAIlS:PIvn: MPU S -56i NAD 1927 (NADCON CDNDS) Alaska ZoneM Site: M Pt S Pad Co-ordinate (N/E) Reference: Well Plan: MPU S -SE, Tue North Well: Plan: MPU S -56i Wftk.1 (TVD) Reference: MPU &%M-buih RKB @ 63.4 -ft 36.90 5purry Orilii.+g Wellbore: MPU S -58i Measured Depth Reference: MPU S-Sa M.built RKB @63.4 -ft +N/ -S +&-W N.Ah g Eaging Latitbude l..gilu e Calalzden Method: Minim curven,re 0.00 0.00 5999884.82 565478.70 70'24'36.487N 149° 28'0.588 W Plan: MPU S-56 wp03 SURVEY PROGRAM GLOBAL FILTER APPLIED. All wellpaths within 200'+ 100/1000 of reference Dete:2019-07-o5T0600:00 velidrted:Yee version: 26.50 To 14368.13 m OepM From Depth To Sury y1Plen Tool CASING DETAILS 2650 900.00 MPU S-56 p03 (MPU S%) 3 Gyro -GC Cep LadderlS.F. Plots 900.00 55TI92 MPU S%yp03(MPU S-%) 3_MWD+IFR2+MS+Sap TVD TVDSS MD Site Name 55-92 14368.13 MPU S -W M,03 (MPU S%) 3_MWD+IFR2+MS.Se9 1 of 2 4063.40 4000.00 5577.92 9-5/8 9 5/8" X 12 1/4" 4043.40 3980.00 14368A3 6-5/8 65/8"s81/2" 180.00 � ` X150.00 V - - - X120.00 o j m MPU S- _ 7 Wp03� I t 1 n 90.00--7: m MPS -3 m 60.00 U MPU S- 02 wpl0 jI..........I . ....... - .._. _..- _ ..._....�j - _... -.- j. ......_._ -.... ___._... MPU S- 03 I MPS -4t MPS -4& 0.00 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 Measured Depth (600 usft/in) 4.00-- I � L I --- ---- - j c O .00 m 2.00-- I I to Collision Collision Risk Procedures Req. U Collision Avoidance Req. 1.00- .00 - No -Go Zone - Stop Drilling I NOERRORS 0.00 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 Measured Depth (600 usft/in) Hilcorp Alaska, LLC Milne Point M Pt S Pad Plan: MPU S -56i MPU S -56i MPU S-56 wp03 Sperry Drilling Services Clearance Summary Anticollision Report 10 February, 2020 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S-561 - MPU S-56 wp03 Well Coordinates: 5,999,884.82 N, 565,478.70 E (70° 24' 36.49" N, 149° 28' 00.59" W) Datum Height: MPU S-56 As -built RKB @ 63.40usft Scan Range: 5,577.92 to 14,368.13 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91E Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Hilcorp Alaska, LLC Milne Point Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-561 - MPU S -56i - MPU S-56 wp03 Scan Range: 5,577.92 to 14,368.13 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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 M Pt H Pad MPH -05 - MPH -05 - MPH -05 MPH -05 - MPH -05 - MPH -05 MPH -06 - MPH -06 - MPH -06 MPH -06 - MPH -06 - MPH -06 MPH -06 - MPH -06 - MPH -06 MPH -08 - MPH -08 - MPH -08 MPH -08 - MPH -08 - MPH -08 MPH -08 - MPH -08 - MPH -08 MPH -08 - MPH -08A - MPH -08A MPH -08 - MPH -08A - MPH -08A MPH -08 - MPH -08A - MPH -08A MPH -08 - MPH-08APB1 - MPH-08APB1 MPH -08 - MPH-08APB1 - MPH-08APB1 MPH -08 - MPH-08APB1 - MPH-08APB1 MPH -08 - MPH -08B - MPH -08B MPH -08 - MPH -08B - MPH -08B MPH -08 - MPH -08B - MPH -08B MPH -08 - MPH-08BL1 - MPH-08BL1 MPH -08 - MPH-08BL1 - MPH-08BL1 MPH -08 - MPH-08BL1 - MPH-08BL1 MPH -08 - MPH-08BPB1 - MPH-08BPB1 MPH -08 - MPH-08BPB1 - MPH-08BPB1 MPH -08 - MPH-08BPB1 - MPH-08BPB1 MPH -12 - MPH -12 - MPH -12 MPH -17 - MPH -17 - MPH -17 M Pt S Pad MPS -06 - MPS -06 - MPS -06 10 February, 2020 - 19:08 14,353.82 850.05 14,353.82 714.30 8,295.22 6.262 Centre Distance Pass - 14,368.13 850.12 14,368.13 712.25 8,285.46 6.166 Clearance Factor Pass - 12,352.34 1,343.85 12,352.34 1,195.60 9,603.90 9.065 Centre Distance Pass - 12,627.92 1,353.39 12,627.92 1,185.94 9,385.15 8.082 Ellipse Separation Pass - 13,652.92 1,522.04 13,652.92 1,300.55 8,517.46 6.872 Clearance Factor Pass - 13,677.92 555.37 13,677.92 149.61 8,451.97 1.369 Clearance Factor Pass - 13,727.92 537.09 13,727.92 147.19 8,425.84 1.378 Ellipse Separation Pass - 13,973.34 494.64 13,973.34 227.43 8,285.12 1.851 Centre Distance Pass - 13,677.92 555.37 13,677.92 148.78 8,452.75 1.366 Clearance Factor Pass - 13,727.92 537.09 13,727.92 146.41 8,426.62 1.375 Ellipse Separation Pass - 13,973.34 494.64 13,973.34 226.98 8,285.90 1.848 Centre Distance Pass - 13,677.92 555.37 13,677.92 148.78 8,452.75 1.366 Clearance Factor Pass - 13,727.92 537.09 13,727.92 146.41 8,426.62 1.375 Ellipse Separation Pass - 13,973.34 494.64 13,973.34 226.98 8,285.90 1.848 Centre Distance Pass - 13,677.92 555.37 13,677.92 149.31 8,452.75 1.368 Clearance Factor Pass - 13,727.92 537.09 13,727.92 146,91 8,426.62 1.377 Ellipse Separation Pass - 13,973.34 494.64 13,973.34 227.27 8,285.90 1.850 Centre Distance Pass - 13,677.92 555.37 13,677.92 148.46 8,452.75 1.365 Clearance Factor Pass - 13,727.92 537.09 13,727.92 146.11 8,426.62 1.374 Ellipse Separation Pass - 13,973.34 494.64 13,973.34 226.82 8,285.90 1.847 Centre Distance Pass - 13,677.92 555.37 13,677.92 148.47 8,452.75 1.365 Clearance Factor Pass - 13,727.92 537.09 13,727.92 146.12 8,426.62 1.374 Ellipse Separation Pass - 13,973.34 494.64 13,973.34 226.82 8,285.90 1.847 Centre Distance Pass - 14,368.13 1,301.01 14,368.13 915.40 7,967.96 3.374 Clearance Factor Pass - 14,368.13 1,355.83 14,368.13 1,019.22 6,897.79 4.028 Clearance Factor Pass - 5,577.92 1,072.94 5,577.92 981.44 4,812.72 11.726 Clearance Factor Pass - Page 2 of 9 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S -56i - MPU S-56 Wp03 Scan Range: 5,577.92 to 14,368.13 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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 MPS -13 - MPS -13 - MPS -13 5,577.92 1,018.60 5,577.92 949.04 4,614.10 14.643 Clearance Factor Pass - MPS -I4 -MPS -I4 -MPS -14 7,256.12 779.12 7,256.12 727.54 5,040.22 15.104 Centre Distance Pass - MPS -14 - MPS -14 - MPS -14 7,402.92 791.76 7,402.92 716.66 5,081.31 10.543 Ellipse Separation Pass - MPS -14 - MPS -14 - MPS -14 7,977.92 1,042.47 7,977.92 885.10 5,242.31 6.625 Clearance Factor Pass - MPS -17 -MPS -17 -MPS -17 9,183.57 133.06 9,183.57 84.66 7,329.09 2.749 Centre Distance Pass - MPS -17 - MPS -17 - MPS -17 9,327.92 184.27 9,327.92 15.01 7,395.96 1.089 Clearance Factor Pass - MPS -17 -MPS -171 -1 -MPS -171-1 9,115.29 87.78 9,115.29 45.57 7,286.72 2.080 Centre Distance Pass - MPS -17 - MPS -17L1 - MPS -171-1 S MPS -17 - MPS -17L1 -MPS-17L1 ® - MPS -20 - MPS -20 - MPS -20 ® - MPS -20 - MPS -20 - MPS -20 MPS -20 - MPS -20 - MPS -20 MPS -2I -MPS -2I -MPS -21 9,440.44 1,021.21 9,440.44 930.28 5,726.30 11.231 Centre Distance Pass - M PS -21 - MPS -21 - MPS -21 9,727.92 1,048.87 9,727.92 903.85 5,881.83 7.232 Ellipse Separation Pass - MPS -2I -MPS -2I -MPS -21 10,552.92 1,381.99 10,552.92 1,117.68 6,338.82 5.229 Clearance Factor Pass - MPS -22 -MPS-22 - MPS -22 6,566.10 418.20 6,566.10 380.10 4,887.81 10.977 Centre Distance Pass - MPS -22 - MPS -22 - MPS -22 6,577.92 418.38 6,577.92 379.96 4,885.93 10.889 Ellipse Separation Pass - MPS -22 - MPS -22 - MPS -22 6,802.92 483.92 6,802.92 433.23 4,850.00 9.546 Clearance Factor Pass - MPS -23 - MPS -23 - MPS -23 5,616.59 144.75 5,616.59 109.61 6,560.21 4.120 Centre Distance Pass - MPS -23 - MPS -23 - MPS -23 5,652.92 148.19 5,652.92 109.06 6,542.82 3.787 Ellipse Separation Pass - MPS -23 - MPS -23 - MPS -23 5,752.92 185.63 5,752.92 126.79 6,489.58 3.154 Clearance Factor Pass - MPS -23 - MPS -231-1 - MPS -23L1 5,577.92 103.12 5,577.92 66.19 6,564.02 2.792 Ellipse Separation Pass - MPS -23 - MPS -231-1 - MPS -231-1 5,612.21 98.65 5,612.21 69.37 6,548.13 3.369 Centre Distance Pass - MPS -23 -MPS -23L1 -MPS -23L1 5,702.92 125.58 5,702.92 73.94 6,503.88 2.432 Clearance Factor Pass - MPS -24 - MPS -24 - MPS -24 - = MPS -24 - MPS -24 - MPS -24 6,446.42 42.98 6,446.42 16.34 5,494.24 1.613 Centre Distance Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 6,327.92 497.21 6,327.92 393.44 5,033.00 4.791 Clearance Factor Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 6,527.92 450.43 6,527.92 364.63 5,033.00 5.250 Ellipse Separation Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 6,589.56 447.52 6,589.56 366.74 5,033.00 5.540 Centre Distance Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 ® _ 10 February, 2020 - 19:08 Page 3 of 9 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S -56i - MPU S-56 wp03 Scan Range: 5,577.92 to 14,368.13 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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 MPS -24 - MPS-24PB2 - MPS-24PB2 6,446.42 42.98 6,446.42 16.19 5,494.24 1.604 Centre Distance Pass - MPS -25 - MPS -25 - MPS -25 8,643.18 151.35 8,643.18 73.15 5,529.84 1.935 Centre Distance Pass - MPS -25 - MPS -25 - MPS -25 8,727.92 172.81 8,727.92 48.57 5,516.75 1.391 Clearance Factor Pass - MPS -25 - MPS -251-1 - MPS -251-1 8,643.18 151.35 8,643.18 73.13 5,529.84 1.935 Centre Distance Pass - MPS -25 - MPS -251-1 - MPS -251-1 8,727.92 172.81 8,727.92 48.47 5,516.75 1.390 Clearance Factor Pass - MPS 26 - MPS -26 - MPS -26 5,682.75 741.37 5,682.75 685.80 4,595.35 13.341 Centre Distance Pass - MPS -26 - MPS -26 - MPS -26 5,727.92 743.21 5,727.92 683.51 4,609.03 12.450 Ellipse Separation Pass - MPS -26 - MPS -26 - MPS -26 6,127.92 899.98 6,127.92 806.27 4,684.67 9.604 Clearance Factor Pass - MPS -27 - MPS -27 - MPS -27 9,475.38 744.73 9,475.38 643.00 5,812.04 7.321 Centre Distance Pass - MPS -27 - MPS -27 - MPS -27 9,802.92 783.61 9,802.92 607.00 6,030.17 4.437 Ellipse Separation Pass - MPS -27 - MPS -27 - MPS -27 10,252.92 937.40 10,252.92 681.62 6,329.46 3.665 Clearance Factor Pass - MPS -27 - MPS -27L1 - MPS -271-1 9,475.38 744.73 9,475.38 643.16 5,812.04 7.333 Centre Distance Pass - MPS -27 - MPS -271-1 - MPS -271-1 9,802.92 783.61 91802.92 607.36 6,030.17 4.446 Ellipse Separation Pass - MPS -27 - MPS -271-1 - MPS -271-1 10,252.92 937.40 101252.92 682.19 6,329.46 3.673 Clearance Factor Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 9,475.38 744.73 9,475.38 642.46 5,812.04 7.282 Centre Distance Pass - MPS -27 - MPS -27P81 - MPS-27PB1 9,802.92 783.61 9,802.92 606.46 6,030.17 4.423 Ellipse Separation Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 10,252.92 937.40 10,252.92 681.08 6,329.46 3.657 Clearance Factor Pass - MPS -28 - MPS -28 - MPS -28 MPS -28 - MPS -28 - MPS -28 ® S MPS -28 - MPS -28 - MPS -28 MPS -28 - MPS-28PB1 - MPS-28PB1 S MPS -28 - MPS-28PB1 - MPS-28PB1 MPS -28 - MPS-28PB1 - MPS-28PB1 MPS -28 - MPS-28PB2 - MPS-28PB2 MPS -28 - MPS-28PB2 - MPS-28PB2 ® ® O MPS -28 - MPS-28PB2 - MPS-28PB2 MPS -29 -MPS -29 -MPS -29 MPS -29 -MPS -29 -MPS -29 MPS -29 - MPS -29 - MPS -29 MPS -29 - MPS -29L1 - MPS -291-1 ® ® ® - 10 February, 2020 - 19:08 Page 4 of 9 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S -56i - MPU S-561- MPU S-56 Wp03 Scan Range: 5,577.92 to 14,368.13 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,500.00 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 MPS -30 - MPS -30 - MPS -30 7,883.77 841.78 7,883.77 789.14 4,930.26 15.990 Centre Distance Pass - MPS -30 - MPS -30 - MPS -30 8,077.92 860.61 8,077.92 775.44 5,011.85 10.105 Ellipse Separation Pass - MPS -30 - MPS -30 - MPS -30 8,702.92 1,131.21 8,702.92 956.77 5,268.38 6.485 Clearance Factor Pass - MPS -3I -MPS -3I -MPS -31 6,612.39 1,176.67 6,612.39 1,142.37 4,558.11 34.300 Centre Distance Pass - MPS -3I -MPS -3I -MPS -31 6,727.92 1,182.68 6,727.92 1,138.16 4,605.03 26.563 Ellipse Separation Pass - MPS -3I -MPS -3I -MPS -31 7,652.92 1,609.54 7,652.92 1,487.06 4,768.70 13.142 Clearance Factor Pass - MPS -32 - MPS -32 - MPS -32 9,409.31 882.46 9,409.31 782.51 5,597.65 8.829 Centre Distance Pass - MPS -32 - MPS -32 - MPS -32 9,727.92 915.50 9,727.92 748.77 5,813.55 5.491 Ellipse Separation Pass - MPS -32 -MPS -32 -MPS -32 10,302.92 1,125.47 10,302.92 870.43 6,130.02 4.413 Clearance Factor Pass - MPS -33 - MPS -33 - MPS -33 7,302.92 159.46 7,302.92 37.52 4,955.56 1.308 Clearance Factor Pass - MPS -33 - MPS -33 - MPS -33 7,327.92 147.82 7,327.92 37.21 4,959.99 1.336 Ellipse Separation Pass - MPS -33 - MPS -33 - MPS -33 7,389.31 134.91 7,389.31 64.58 4,970.77 1.918 Centre Distance Pass - MPS -33 -MPS -33A -MPS -33A 6,935.67 116.13 6,935.67 60.94 4,960.74 2.104 Centre Distance Pass - MPS -33 - MPS -33A - MPS -33A 7,002.92 135.21 7,002.92 37.55 4,964.61 1.384 Clearance Factor Pass - MPS -34 - MPS -34 - MPS -34 8,701.03 1,356.99 8,701.03 1,292.95 4,925.73 21.192 Centre Distance Pass - MPS -34 - MPS -34 - MPS -34 8,977.92 1,374.21 8,977.92 1,276.73 5,097.91 14.098 Ellipse Separation Pass - MPS -34 - MPS -34 - MPS -34 9,852.92 1,630.29 9,852.92 1,422.03 5,646.60 7.828 Clearance Factor Pass - MPS -34 -MPS -34L1 -MPS -341-1 8,701.03 1,356.99 8,701.03 1,292.95 4,925.73 21.192 Centre Distance Pass - MPS -34 -MPS -34L1 -MPS -341-1 8,977.92 1,374.21 8,977.92 1,276.73 5,097.91 14.098 Ellipse Separation Pass - MPS -34 - MPS -341-1 - MPS -341-1 9,852.92 1,630.29 9,852.92 1,422.03 5,646.60 7.828 Clearance Factor Pass - MPS -34 -MPS -341 -2 -MPS -34L2 8,701.03 1,356.99 8,701.03 1,292.95 4,925.73 21.191 Centre Distance Pass - MPS -34 - MPS -341-2 - MPS -341-2 8,977.92 1,374.21 8,977.92 1,276.73 5,097.91 14.098 Ellipse Separation Pass - MPS -34 - MPS -341-2 - MPS -341-2 9,852.92 1,630.29 9,852.92 1,422.03 5,646.60 7.828 Clearance Factor Pass - MPS -35 - MPS -35 - MPS -35 14,368.13 1,274.55 14,368.13 937.70 14,804.00 3.784 Clearance Factor Pass - MPS -35 - MPS-35PB1 - MPS-35PB1 8,457.02 1,493.75 8,457.02 1,429.58 4,760.46 23.278 Centre Distance Pass - MPS-35-MPS-35PB1 -MPS-35PB1 8,702.92 1,507.43 8,702.92 1,416.21 4,898.82 16.526 Ellipse Separation Pass - MPS -35 - MPS-35PS1 - MPS-35PB1 9,252.92 1,631.81 9,252.92 1,474.54 5,239.21 10.376 Clearance Factor Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 8,457.02 1,493.75 8,457.02 1,429.58 4,760.46 23.278 Centre Distance Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 8,702.92 1,507.43 8,702.92 1,416.21 4,898.82 16.526 Ellipse Separation Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 9,252.92 1,631.81 9,252.92 1,474.54 5,239.21 10.376 Clearance Factor Pass - 10 February, 2020 - 19:08 Page 5 of 9 COMPASS Hileorp Alaska, LLC HALLI CSU R TO N Milne Point Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt S Pad - Plan: MPU S-561 - MPU S-561 - MPU S-56 wp03 Scan Range: 5,577.92 to 14,368.13 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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 MPU S-203 - MPU S-203 - MPU S-203 5,577.92 284.49 5,577.92 240.46 5,660.62 6.460 Ellipse Separation Pass - MPU S-203- MPU S-203 - MPU S-203 5,652.92 304.32 5,652.92 256.82 5,724.27 6.407 Clearance Factor Pass - MPU S-203 - MPU S -203P81 - MPU S-203PB1 5,577.92 284.49 5,577.92 240.46 5,660.62 6.460 Ellipse Separation Pass - MPU S-203 - MPU S-203PB1 - MPU S-203PB1 5,652.92 304.32 5,652.92 256.82 5,724.27 6.407 Clearance Factor Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 5,577.92 284.49 5,577.92 240.46 5,660.62 6.460 Ellipse Separation Pass - MPU S-203 - MPU S-203PB2 - MPU S-203PB2 5,652.92 304.32 5,652.92 256.82 5,724.27 6.407 Clearance Factor Pass - Plan: MPU S-201 - MPU S-201 - MPU S-201 wp07 - a 5,577.92 1,532.56 5,577.92 1,445.23 7,091.89 17.550 Clearance Factor Pass - Plan: MPU S-202 - MPU S-202 - MPU S-202 wp10 - a 5,577.92 870.02 5,577.92 797.89 5,944.97 12.061 Clearance Factor Pass - Proposal Plan: MPU S-206 - MPU S-206 - UGNU#6 -: 7,652.92 353.24 7,652.92 283.73 6,552.86 5.082 Clearance Factor Pass - Proposal Plan: MPU S-206 - MPU S-206 - UGNU#6 -; 7,827.92 273.31 7,827.92 236.89 6,581.89 7.505 Ellipse Separation Pass - Proposal Plan: MPU S-206 - MPU S-206 - UGNU#6 -; 7,887.56 266.91 7,887.56 238.85 6,591.79 9.513 Centre Distance Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 8,752.92 280.20 8,752.92 205.20 7,127.99 3.736 Clearance Factor Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 8,877.92 222.98 8,877.92 177.48 7,152.78 4.901 Ellipse Separation Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 8,935.29 215.78 8,935.29 180.71 7,164.16 6.154 Centre Distance Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 9,452.92 262.33 9,452.92 185.33 7,672.31 3.407 Clearance Factor Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 9,552.92 217.11 9,552.92 164.55 7,692.14 4.130 Ellipse Separation Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 9,615.74 208.20 9,615.74 167.85 7,704.60 5.160 Centre Distance Pass - Proposal Plan: MPU S-209 - MPU S-209 - MPU S-209 10,127.92 267.11 10,127.92 184.28 8,278.39 3.225 Clearance Factor Pass - Proposal Plan: MPU S-209 - MPU S-209 - MPU S-209 10,227.92 220.54 10,227.92 161.09 8,298.22 3.710 Ellipse Separation Pass - Proposal Plan: MPU S-209 - MPU S-209 - MPU S-209 10,296.14 210.16 10,296.14 164.06 8,311.75 4.559 Centre Distance Pass - Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 10,802.92 277.27 10,802.92 191.03 8,783.03 3.215 Clearance Factor Pass - Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 10,927.92 223.52 10,927.92 164.57 8,807.88 3.791 Ellipse Separation Pass - Proposal Plan: MPU S-210 - MPU S-210 - MPU S-210 10,977.51 218.18 10,977.51 167.12 8,817.73 4.273 Centre Distance Pass - RIG: M PU S-57 - MPU S-57 - MPU S-57 wp03 7,676.72 735.49 7,676.72 650.24 6,805.85 8.627 Centre Distance Pass - RIG: MPU S-57 - MPU S-57 - MPU S-57 wp03 14,368.13 742.88 14,368.13 454.05 13,496.44 2.572 Clearance Factor Pass - 10 February, 2020 - 19:08 Page 6 of 9 COMPASS HALLIBURTON Anticollision Report for Plan: MPU S -56i - MPU S-56 wp03 Survey tool program From To Survey/Plan (usft) (usft) 26.50 900.00 MPU S-56 wp03 900.00 5,577.92 MPU S-56 wp03 5,577.92 14,368.13 MPU S-56 wp03 Ellipse error terms are correlated across survey tool tie -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 Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 3_Gyro-GC_Csg 3 MWD+IFR2+MS+Sag 3_MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point 10 February, 2020 - 19:08 Page 7 of 9 COMPASS HALLIBLIRTON Project: Milne Point REFERENCE INFORMATION WELL DEL4[IS:PIan:MPUS56i NAD1927(4ADCONCONUS) Alaska ZOt1e04 Site: M Pt S Pad Co-ordinate (NIE) Rererence: Well Plan: MPU S-561, True North 36.90 9porry OrNlina Well: Plan: MPU S-56i W-I (TVD) Rererence: MPU S_WM-0Jft RKB @ 63A0ualt Measured Depth Rererence: MPU S-WM-Euift RKB @ 6JA.- TN/-S IE/-W NOltllltlg Eal g Lati=de L..gim C Wellbore: MPU S-56i --tion Method: Mmimum Curvatura 0.00 0.00 5999884.82 565478.70 70°2436.487N 149=28'0.588 Plan: MPU 5-56 wp03 SURVEY PROGRAM GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Em Date: 2019.07-o5T00:00 W validated: Ye: veli..: 26.50 To 14368.13 Depth From Depth To Su,.ylPlan -I 900.00 MPU SSS S-m3_Gyro-GC_Csg CASING DETAILS Ladder/ S. F. Plots vp03 (MPU ) 90026.0050 SS MPU-M1-3(MPU S-56) 3_MWD+IFRNMS+Sag n .92 5571.92 11368.13 MPUS-56w 03(MPUS56) 3_ MWD.IFR2+MS.Sag TVD TVDSS MD Si- N- 2 of G 4063.40 4000.00 5577.92 9-5/8 9 5B" x 12 1/4" 4043.40 3980.00 14368.13 6-5/8 6 5/8" s 8 1/2" 180.00 r C I I II It MPS-33 C) coo,20.00 -- I w I 90.00- 0.00 a) a) MPS-28 _ N I aci 60.00 I I � MPS 28PB? ` c 30.00---- 0.00 d - 0 0 0.00 5225 5700 6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11675 12350 12825 13300 13775 14250 Measured Depth (950 usft/in) 4.00-r__ I 3.00 m LL c 1 I i 2.00 n !,Collision Ril k Procedur N Collision Avoidance Reqs. j 1.00- .00 r r to-Go Zone - Stop Drilli0g 0.00IT lilITIF11111 5225 5700 6175 6650 7125 7600 8075 8550 9025 9500 9975 10450 10925 11400 11875 12350 12825 13300 13775 14250 Measured Depth (950 usft/in) Boyer, David L (CED) From: Cody Dinger <cdinger@hilcorp.com> Sent: Friday, February 14, 2020 11:07 AM To: Davies, Stephen F (CED); Boyer, David L (CED) Cc: Joseph Engel Subject: MPU 5-56 Directional Plan Attachments: MPU S -56i wp03_GEO.TXT; MPU S -56i wp03_GIS.TXT; MPU S -56i wp03.txt Steve/Dave, I have attached the directional plan for MPU 5-56 and will deliver the permit this afternoon. The well will not be pre - produced. Thanks, Cody Dinger Hilcorp Alaska, LLC Drilling Tech 907-777-8389 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. Transform Points Source coordinate system 1A 5 Target coordinate system M a Adbers Equal Area (-150) State Plane 1527 - Alaska Zone 4 Datum: NAD 1927 - North America Datum of 1927 (Mean) I Datum: 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 Ctrl+C to !copy and Ctd+Vto paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. I < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: W Q_ �S - S O PTD: -;), o - C) 6 Development V/ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: M d h e C O t h+ POOL: SG T'0. eP — D l a -P -P 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. Spacing Approval to produce/inject is contingent upon issuance of a Exception conservation 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: Non- production or production testing of coal bed methane is not allowed for 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. (Company) 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 also required for this well: Well Logging Requirements 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. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT S-56 _Program SER Well bore seg ❑ PTD#: 2200170 Company Hilcorp Alaska LLC Initial Class/Type SER / PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached_ _ NA_ 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - 3 Unique well _name andnumber_________________________ Yes___ 4 Well located in-a_d_efined_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 plat_included--------- ______________ -_ Yes_______ 9 -Operator only affected party --------------------- _ ----------------- Yes _______ , 10 Operator has -appropriate _bond in force - _ _ - - Yes _ - - - - - _ - 11 Permit can be issued without conservation order_ Yes Appr Date 12 Permit -can be issued _without administrative_approval - - - - - - - _ _ _ _ Yes _ 13 -Can permit beapproved before 15 -day wait- - - - - - - - Yes DLB 2/19/2020 - - - - - - - - - - - - - - - - - - - - _ - - - - _ - - - _ - - - _ _ _ - _ _ _ _ _ _ _ 14 Well located within area and -strata authorized by Injection Order # (put 10# in_ comments)- (For -Yes . - - _ _ Area Injection Order No._ 1.0-B. - - - - - - - - _ _ - 15 All we] -Is -wit -hi -n -1/4 -mile -area -of 1/4_mile_area_of review identified (For service well only)- - - - - - - - - - - - - - Yes - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ - - - _ _ _ _ _ _ _ _ _ _ _ 16 Pre -produced injector. duration_of pre production Less than 3 months_ (For -service well only) _ _ Yes S-56 will -not-be -pre-produced - - - - - - - - - - - - - - - - - - 17 _N_onconven. ga_s conforms to AS31105:030Q.1_.A),Q.2_.A-D) - - - - - - _ NA 18 -Conductor string -provided _ - - - - - - - - - - - - - - - - _Yes 20" con_ductor_set _at 107 ft _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 19 Surface casing -protects all -known_ USDWs - - - - - - - - - - - - - - - - - - NA_ - - - - - _ NO auquifers _ - - - 20 CMT_vol _adequate _to circulate -on conductor _& surf _csg - - - - - - - _ - - - _ _ _ _ - - - Yes using 2_stage cementiob.,._ES-tool at 2500 ft MD_ 21 CMT_vol _adequate to tie-in long string to surf csg_ - _ _ _ _ - NA_ 9 5/5" casing set in -Schrader bluff pool._ 22 CMT will coverall known -productive horizons_ Yes - - _ 4.5"I_C_D_later_al_with swell packers in th_e_injection zone._ _ 23 Casing designs adequate for C,_T, B -permafrost- - - - - - - - - - - - - - - - - - - - - - - - - Yes BTC ca_lcs supplied_ - - - - _ - 24 Adequate -tankage -or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - Yes _ - _Innovation rig has steel pits. - - - - - ------------------------------------ 25 If_a_re-drill, has- a1.0-403 for abandonment been approved - - -- NA____________________________________________________________________ 26 Adequate wellbore separation.proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Close_crossing with several -SB- wells ... geologically separated by TVD (Ne sand -vs OA) - - - - - - - - 27 If_diverter required, does it meet_regu_lations_ - - - - _ - Yes - - - - - _ _ Appr Date 28 Drilling fluid_ program schematic &equip list adequate_ _ - _ Yes - Max for press =_8,5-ppg-(wil_l drill with 8.8 -9.5 ppg mud) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ GLS 2/28/2020 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - - - Yes Innovation has 5000 psi WP BOPE - _ _ _ - - - _ - _ 30 BOPE_press rating appropriate; test to -(put prig in comments)_ - - - - - Yes MASP= 1381 psi -will test_B_O_PE_to 3000_psi_(annular to 2500 -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 - - - - - - -- - - - - - - - No_ - _ - 34 Mechanical_ condition of wells within AOR verified (For -service well only) _ _ Yes - - _ AOR completed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit_can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ - - - - - - - Yes H2S not anticipated from drilling of offset wells; however, rig ha -s.1-125 sensors and alarms.- _ Geology 36 Data -presented on potentialoverpressur_ezones-__________ Yes_. ___________________ Appr Date 37 Seismicanalys_is_ofshallow gas -zones _ - _ - _ - - - - - -- - - . - - - - -- - - - - - - - - - - - - - - - - - - - - - - DLB 2/19/2020 38 Seabed condition survey -(if off -shore) - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ NA_ -------------------------------------------------------------- 39 Contact name/phone for weekly -progress reports_ [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ Geologic Engineering Public Commissioner: Date: Commissioner: Date Com mis n Date r�fi� V2- 12_r mac, 31z1�� lalgO